-------
HDOH ID 9-102771

SURVEY OF RELEASE DETECTION METHODS - Red Hill Tanks F-l to F-20

List of Applicable Method, or Combination of Methods, of Release Detection

F-5

F-6

F-7

F-8

~ Conducted an annual tank tightness test (TTT) that can detect a 0.5 gallon per

~

~

El

E

hour (gph) leak rate from any portion of the tank that routinely contain product.

HAR 11-280.1-43(10)(A)









IZHUed an automatic tank gauging system to perform release detection at least

~

~

~



evefythirty-one days that can detect a leak rate less than or equal to one gallon









per hounv









AND









~ Conducted a tanlTbghtness test (TTT) that can detect a 0.2 gallon per hour leak

~



~

~

rate performed at leasb^very three years.









HAR 11-280.1-43(10)(B)









~ Used an automatic tank gauging sWem to perform release detection at least



~

~

~

every thirty-one days that can detecta^eak rate less than or equal to two gallon^









per hour.









AND









~ Conducted a tank tightness test (TTT) that can detecN^0.2 gallon^rer hour leak

~

~

~

~

rate performed at least every two years.









HAR 11-280.1-43(10HC)









~ Performed vapor monitoring with a tracer compgwda placed in the riK^k system,

~

~

~

~

capable of detecting a 0.1 gallon per hour lejikrate at least every two ye^.









HAR 11-280.1-43(10)(D) N.









CH Performed inventory control (conpkJcted in accordance with Department of



~

~

~

Defense Directive 4140.25, A^fiAirport Fuel Facility Operations and









Maintenance GuidanceMcfnual, or equivalent procedures) at least every thirty-









one days that can detect a leak equal to or less than 0.5 percent of flow-through.









AND









~ Performe^atank tightness test (TTT) that can detect a 0.5 gallon per hour leak

~

~



~

rateafTeast every two years; OR performed vapor monitoring or groundwater









aronitoring at least every thirty-one days.









^AR 11-280.1-43(10)(E)









Comments:









MTC tank tightness test is third party certified by Ken Wilcox Associates.







Michael Baker International (Michael Baker) professional engineer certifies tank tightness test results.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 51 of 97

-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS - Red Hill Tanks F-l to F-20

General Requirements for All Tanks Using A Method, or A Combination of
Methods, of Release Detection

F-5

F-6

F-7

F-8

8

-------
HDOH ID 9-102771

SURVEY OF RELEASE DETECTION METHODS - Red Hill Tanks F-l to F-20

List of Applicable Method, or Combination of Methods, of Release Detection

F-9

F-10

F-ll

F-12

El Conducted an annual tank tightness test (TTT) that can detect a 0.5 gallon per
hour (gph) leak rate from any portion of the tank that routinely contain product.

HAR11-280.1-43(10)(A)

IZI

IZI

0

IZI

CkUsed an automatic tank gauging system to perform release detection at least
ewsvthirty-one days that can detect a leak rate less than or equal to one gallon
per hohv
AND

~ Conducted a tamKjghtness test (TTT) that can detect a 0.2 gallon per hour leak
rate performed at leaH^very three years.

HAR 11-280.1-43(10)(B)

~
~

~

~
n

~

n Used an automatic tank gauging-s^stem to perform release detection at least
every thirty-one days that can detecN*Teak rate less than or equal to two gallon^
per hour.

AND

~ Conducted a tank tightness test (TTT) that can detebt^a 0.2 gallon hour leak
rate performed at least every two years.

HAR 11-280.1-43(10)(C)

~

~
~

~
~

~
~

D Performed vapor monitoring with a tracer compoufwplaced in the*i^nk system,
capable of detecting a 0.1 gallon per hour leaLr^te at least every two yfeqrs.

HAR 11-280.1-43(10)(D)

~

~

~

~

D Performed inventory control (conch^fed in accordance with Department of
Defense Directive 4140.25, AT^(irport Fuel Facility Operations and
Maintenance Guidance M^rfual, or equivalent procedures) at least every thirty-
one days that can deti»
-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS - Red Hill Tanks F-l to F-20

General Requirements for All Tanks Using A Method, or A Combination of
Methods, of Release Detection

F-9

F-10

F-ll

F-12



Release detection can detect a release from any portion of the UST.

HAR11-280.l-40(a)(l)

~

IZI

IZI

IZI



The release detection is installed, calibrated, operated and maintained in
a5fc*ndance with the manufacturer's instructions, and routine service and
maintenance checks, har n-280.i-40(a)(3)

~

~

~





The release detfe«tion equipment is tested for proper operation at least every
365 days or in a timeYn^me recommended by the equipment manufacturer,
whichever is more frequem>H^Bii-280.i-40(a)(4)

Dates of the last three (3) tests: and ^

n^

-"n

~

~

8
Z

All maintenance and service of the releas&si^tection equipment are con#kj£ted
by a technician with current certification or tralTtmgappropriatetp«*tfe
equipment serviced, har n-280.i-40{a)(4)

Technician's Name: Exp^afiraiftme

~

~

~

~



The release detection equipment meets the D£j»f6rmance requirements
specified for that method, har ii-280.i-40Ui^i

DThe release detection eqj>jfJment is capable of detecting the leak rate

or quantity specifi^Kor that method.

Dlhe probabjjit^of detection (Pd) of 0.95 and the probability of false

alarmJPfc!) of 0.05 are met.

~jarSut Monthly (31-Day) Release Detection for Tanks and Piping Table



~

~

~



iTpe^ase detection requirements are not met, then completed change-in-
service, or closure, harn-280.i-40(c)

~

~

~



Recordkeeping

F-9

F-10

F-ll

F-12

8

All written performance claims pertaining to any release detection system used,
and the manner in which these claims have been justified or tested by the
equipment manufacturer or installer, are maintained for the operating life of
the UST system, har 11-280.1-45(1)

IZI

IZI

IZI

IZI

§



The results of any sampling, testing, or monitoring are maintained for at least
three (3) years, har u-280.i-45(2)

~

0

~

~

8

W

All records that the equipment being utilized to monitor or maintain the UST
system is designed to produce are maintained for at least three (3) years after
the records are generated, har ii-280.i-4S(3)

IZI

IZI

IZI

~

8

rH

W

Written documentation of all calibration, maintenance, and repair of release
detection equipment permanently located on-site are maintained for at least
three (3) years, har ii-280.i-4S(4)

IZI

~

IZI

~

Comments:

MTC tank tightness test is third party certified by Ken Wilcox Associates.

Michael Baker International (Michael Baker) professional engineer certifies tank tightness test results.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 54 of 97

-------
HDOH ID 9-102771

SURVEY OF RELEASE DETECTION METHODS - Red Hill Tanks F-l to F-20

List of Applicable Method, or Combination of Methods, of Release Detection

F-13

F-14

F-15

F-16

0 Conducted an annual tank tightness test (TTT) that can detect a 0.5 gallon per
hour (gph) leak rate from any portion of the tank that routinely contain product.

HAR11-280.1-43(10)(A)

~

~

~

~

D^sed an automatic tank gauging system to perform release detection at least
ev^%thirty-one days that can detect a leak rate less than or equal to one gallon
per houKw
AND

D Conducted a tan^^fc^^htness test (TTT) that can detect a 0.2 gallon per hour leak
rate performed at leasS^very three years.

HAR 11-280.1-43(10)(B)

~
~

~

uy

~
~

~

~ Used an automatic tank gaugingsy^tem to perform release detection at least
every thirty-one days that can detectVjeak rate less than or equal to two gallon?''
per hour.

AND

D Conducted a tank tightness test (TTT) that can detectsa 0.2 gallonja^r hour leak
rate performed at least every two years.

HAR 11-280.1-43(10)(C)

~

~
~

~
~

~
~

n Performed vapor monitoring with a tracer compoyrra placed in thet&qk system,
capable of detecting a 0.1 gallon per hour lea|trate at least every two yeSns.

HAR 11-280.1-43(10)(D)

~

~

~

~

n Performed inventory control (conducted in accordance with Department of
Defense Directive 4140.25, AT^frtirport Fuel Facility Operations and
Maintenance Guidance Mafiual, or equivalent procedures) at least every thirty-
one days that can detect a leak equal to or less than 0.5 percent of flow-through.
AND

~ Performed^ank tightness test (III) that can detect a 0.5 gallon per hour leak
rate aj^ast every two years; OR performed vapor monitoring or groundwater
m^mtoring at least every thirty-one days.

HftRll-280.1-43(10)(Ej

\D
~

~
~

~

~
~

Comments:

MTC tank tightness test is third party certified by Ken Wilcox Associates.

Michael Baker International (Michael Baker) professional engineer certifies tank tightness test results.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 55 of 97

-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS - Red Hill Tanks F-l to F-20

General Requirements for All Tanks Using A Method, or A Combination of
Methods, of Release Detection

F-13

F-14

F-15

F-16



Release detection can detect a release from any portion of the UST.

HAR11-280.l-40(a)(l)

~

~

~

~



s^he release detection is installed, calibrated, operated and maintained in
ac^tK^ance with the manufacturer's instructions, and routine service and
maintenSlK^checks. har n-280.i-40(a)(3)

~

~

~





The release deration equipment is tested for proper operation at least every
365 days or in a time^sqie recommended by the equipment manufacturer,
whichever is more frequer\V>iA^ii-280.i-40(a)(4)

Dates of the last three (3) tests: and



<^u

~

~

8
Z

All maintenance and service of the release-detection equipment are con^Urffed
by a technician with current certification or traiTtmgappropriate tp^tfe
equipment serviced, har n-280.i-40{a)(4)

Technician's Name: Exp^pHraTftme;

~

~

~

~



The release detection equipment meets the p^f^rmance requirem&Hts
specified for that method, har n-280.i-4otpH4)

D The release detection egj^Jment is capable of detecting the leak rate "

or quantity specifig^for that method.

D The probabjlifcfof detection (Pd) of 0.95 and the probability of false

alarm^Pfa) of 0.05 are met.

~^Hfout Monthly (31-Day) Release Detection for Tanks and Piping Table



~

~

~



l£>tffease detection requirements are not met, then completed change-in-
service, or closure, harii-280.i-40(c)

~

~

~



Recordkeeping

F-13

F-14

F-15

F-16

8

All written performance claims pertaining to any release detection system used,
and the manner in which these claims have been justified or tested by the
equipment manufacturer or installer, are maintained for the operating life of
the UST system, har 11-280.1-45(1)

IZ1

EZ1

~

~

§



The results of any sampling, testing, or monitoring are maintained for at least
three (3) years, har u-280.i-45(2)

~

~

~

~

8

W

All records that the equipment being utilized to monitor or maintain the UST
system is designed to produce are maintained for at least three (3) years after
the records are generated, har ii-280.i-4S(3)

~

~

~

~

8

rH

W

Written documentation of all calibration, maintenance, and repair of release
detection equipment permanently located on-site are maintained for at least
three (3) years, har ii-280.i-4S(4)

~

~

~

~

Comments:

MTC tank tightness test is third party certified by Ken Wilcox Associates.

Michael Baker International (Michael Baker) professional engineer certifies tank tightness test results.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 56 of 97

-------
HDOH ID 9-102771

SURVEY OF RELEASE DETECTION METHODS - Red Hill Tanks F-l to F-20

List of Applicable Method, or Combination of Methods, of Release Detection

F-17

F-18

F-19

F-20

0 Conducted an annual tank tightness test (TTT) that can detect a 0.5 gallon per
hour (gph) leak rate from any portion of the tank that routinely contain product.

HAR11-280.1-43(10)(A)

12

IZ1

El

~

~"Used an automatic tank gauging system to perform release detection at least
ewc^thirty-one days that can detect a leak rate less than or equal to one gallon
per houK,.

AND

~

~

~



D Conducted a tank^i^htness test (TTT) that can detect a 0.2 gallon per hour leak
rate performed at lea^ts^very three years.

HAR 11-280.1-43(10)(B)

~



~

~

n Used an automatic tank gaugingSy^tem to perform release detection at least
every thirty-one days that can detecrisleak rate less than or equal to two gallon^
per hour.

AND /



~

~

~

C] Conducted a tank tightness test (TTT) that can detectsa 0.2 gallono^r hour leak
rate performed at least every two years.

HAR 11-280.1-43(10)(C)

~

~

~

~

D Performed vapor monitoring with a tracer compouiroplaced in theraqk system,
capable of detecting a 0.1 gallon per hour leajj/iiite at least every two yefcHs.

HAR 11-280.1-43(10)(D)

~

~

~

~

~ Performed inventory control (condj^fed in accordance with Department of
Defense Directive 4140.25, AT^Airport Fuel Facility Operations and
Maintenance Guidance M#wuial, or equivalent procedures) at least every thirty-
one days that can deject a leak equal to or less than 0.5 percent of flow-through.
AND



~

~

~

~ Performeda<^ank tightness test (III) that can detect a 0.5 gallon per hour leak
rate atj^ast every two years; OR performed vapor monitoring or groundwater
mprfltoring at least every thirty-one days.

Hp/ni-280.1-43(10)(Ej

~

~



~

Comments:

MTC tank tightness test is third party certified by Ken Wilcox Associates.

Michael Baker International (Michael Baker) professional engineer certifies tank tightness test results.
RD documents were available at the time of the inspection.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 57 of 97

-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS - Red Hill Tanks F-l to F-20

General Requirements for All Tanks Using A Method, or A Combination of
Methods, of Release Detection

F-17

F-18

F-19

F-20



Release detection can detect a release from any portion of the UST.

HAR11-280.l-40(a)(l)

~

El

~

13



tAQii-280.i-40(a)(4i

Dates of the last three (3) tests: and ^





~

~

8
Z

All maintenance and service of the releas&"6lQtection equipment are conjluCfed
by a technician with current certification or trairftngappropriate taihe
equipment serviced, har n-280.i-40{a)(4)

Technician's Name: Exp-af^faiffin^:

~

~

~

13



The release detection equipment meets the pep#dfmance requirements
specified for that method, har ii-280.i-40(a)ier

D The release detection equjpffient is capable of detecting the leak rate^

or quantity specifiejpWr that method.

Ol"he probabilij^tffdetection (Pd) of 0.95 and the probability of false

alarm (£#dfof 0.05 are met.

D Fjil«<5ut Monthly (31-Day) Release Detection for Tanks and Piping Table



~

~

~



If rgiecfse detection requirements are not met, then completed change-in-
"Service, or closure, harn-280.i-40(c)

~

~

~



Recordkeeping

F-17

F-18

F-19

F-20

8

All written performance claims pertaining to any release detection system used,
and the manner in which these claims have been justified or tested by the
equipment manufacturer or installer, are maintained for the operating life of
the UST system, har 11-280.1-45(1)

~

13

13

0

§



The results of any sampling, testing, or monitoring are maintained for at least
three (3) years, har u-280.i-45(2)

~

~

13

13

8

W

All records that the equipment being utilized to monitor or maintain the UST
system is designed to produce are maintained for at least three (3) years after
the records are generated, harii-280.i-4S(3)

~

~

13

13

8

rH

W

Written documentation of all calibration, maintenance, and repair of release
detection equipment permanently located on-site are maintained for at least
three (3) years, har ii-280.i-4S(4)

~

~

13

13

Comments:

MTC tank tightness test is third party certified by Ken Wilcox Associates.

Michael Baker International (Michael Baker) professional engineer certifies tank tightness test results.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 58 of 97

-------
HDOH ID 9-102771

SURVEY OF RELEASE DETECTION METHODS - Surge Tanks F-ST1 to F-ST4

List of Applicable Method, or Combination of Methods, of Release Detection

F-STl

F-ST2

F-ST3

F-ST4

El Conducted an annual tank tightness test (TTT) that can detect a 0.5 gallon per

~

~

~

~

hour (gph) leak rate from any portion of the tank that routinely contain product.

HAR 11-280.1-43(10)(A)









D4Jsed an automatic tank gauging system to perform release detection at least

~

~

~



ev^n^thirty-one days that can detect a leak rate less than or equal to one gallon









per houtv









AND









D Conducted a tanlNightness test (TTT) that can detect a 0.2 gallon per hour leak

~



~

~

rate performed at leaH^very three years.









HAR 11-280.1-43(10)(B)









~ Used an automatic tank gauging*$vitem to perform release detection at least



~

~

~

every thirty-one days that can detecnssleak rate less than or equal to two gallopy









per hour.









AND









~ Conducted a tank tightness test (TTT) that can deteH»a 0.2 gallop^er hour leak

~

~

~

~

rate performed at least every two years.









HAR 11-280.1-43(10HC)









D Performed vapor monitoring with a tracer comppdlid placed in thet^nk system,

~

~

~

~

capable of detecting a 0.1 gallon per hour le^Krate at least every two yeso.









HAR 11-280.1-43(10)(D) yT









~ Performed inventory control (condflcted in accordance with Department of



~

~

~

Defense Directive 4140.25, A^ftAirport Fuel Facility Operations and









Maintenance Guidance.Manual, or equivalent procedures) at least every thirty-









one days that can defect a leak equal to or less than 0.5 percent of flow-through.









AND









D PerformepHrtank tightness test (TTT) that can detect a 0.5 gallon per hour leak

~

~



~

rate^Heast every two years; OR performed vapor monitoring or groundwater









nronitoring at least every thirty-one days.









jfm 11-280.1-43(10)(E)









Comments:









MTC tank tightness test is third party certified by Ken Wilcox Associates









Michael Baker International (Michael Baker) professional engineer certifies tank tightness test results.

RD documents were available at the time of the inspection.









Need to figure out which Fuel Surge Tank is manifolded and which was out of service.





Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 59 of 97

-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS - Surge Tanks F-ST1 to F-ST4

General Requirements for All Tanks Using A Method, or A Combination of
Methods, of Release Detection

F-ST1

F-ST2

F-ST3

F-ST4

8

£he release detection is installed, calibrated, operated and maintained in
accbmjance with the manufacturer's instructions, and routine service and
maintenafrs^checks. har ii-280.i-40(a)(3)

~

~

~



8

The release detefctiqn equipment is tested for proper operation at least every
365 days or in a time fhraqe recommended by the equipment manufacturer,
whichever is more frequent^fMisii-280,i-40(a)(4)

Dates of the last three (3) tests: and ^





~

~



All maintenance and service of the releasettejection equipment are corjfitffted
by a technician with current certification or traimhg^ppropriate tj>*tfe
equipment serviced, har n-280.i-40(a)(4)

Technician's Name: Em^^fTrafTtm^:

~

~

~

~

8

W

The release detection equipment meets the g^pftfrmance requiremefttt^
specified for that method, har ii-280.i-40MfS)

ED The release detection emj+fJment is capable of detecting the leak rate

or quantity specifigsKor that method.

El The probabjlj4"^of detection (Pd) of 0.95 and the probability of false

alarm^Pfa) of 0.05 are met.

ELPtrSut Monthly (31-Day) Release Detection for Tanks and Piping Table



~

~

~



lfj*t£ase detection requirements are not met, then completed change-in-
service, or closure, har n-280.i-40(c)

~

~

~



Recordkeeping

F-ST1

F-ST2

F-ST3

F-ST4

8

rH

All written performance claims pertaining to any release detection system used,
and the manner in which these claims have been justified or tested by the
equipment manufacturer or installer, are maintained for the operating life of
the UST system, har 11-280.1-45(1)

~

~

~

El

8

rH

W

The results of any sampling, testing, or monitoring are maintained for at least
three (3) years, har 11-280.1-45(2)

~

~

~

El

8

rH
W

All records that the equipment being utilized to monitor or maintain the UST
system is designed to produce are maintained for at least three (3) years after
the records are generated, har 11-280.1-45(3)

El

~

~

El

§
w

Written documentation of all calibration, maintenance, and repair of release
detection equipment permanently located on-site are maintained for at least
three (3) years, har 11-280.1-45(4)

El

~

~

~

Comments:

MTC tank tightness test is third party certified by Ken Wilcox Associates.

Michael Baker International (Michael Baker) professional engineer certifies tank tightness test results.
RD documents were available at the time of the inspection.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 60 of 97

-------
HDOH ID 9-102771

SURVEY OF RELEASE DETECTION FOR PIPING Per Method of Product Dis

pensing

Method of Product Dispensing
~ Safe ~ Unsafe Suction 0 Pressurized

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua
Truck On
Loading Racks

I I Safe Suction: Exempt from release detection if ALL the requirements listed

~

~

~



belows^ met:









~ Intsljelow-grade piping operates at less than atmospheric pressure.

~

~





HAR ll5aHJ-41{b)(6){A)









~ The below-§*%de piping slopes uniformly back to the tank.

~



Su



HAR 11 -280.1









~ There is only one chefek.valve in each section line.

~



~



HAR 11-280.l-41(b)(6)(C)









~ The check valve is located direfcilv below and as close as practicable



~

~



to the suction pump.









HAR 11-280.l-41(b)(6)(D)









~ Compliance with above specifications can beYe^dily deterppHled.

~

~

~



HAR ll-280.1-41(b)(6)(E)









~ Unsafe Suction Piping: If Unsafe Suction piping, then le^fc'ae^te^^ion must

~

~

~



be provided as follows:









HAR 11-280.l-41{b)









~ A. Line tightness test (0.1 gph)









~ Line tightness test conjitftted every 3 years



~

~



~ Able to detect at 1 Yi times operating pressure; OR

cr\

~

~



~ B. Perform one of>He following monthly monitoring methods:









l~l IntersJiti^Tmonitoring

~



~



dO^gph line tightness testing method

~

~





~ Vapor monitoring

~

~





CI Groundwater monitoring

~

~

~



/ ~ Statistical inventory reconciliation

~

~

~



171 Pressurized Piping:

YES

YES

NA

NA

~ Must be provided with an automatic line leak detector (ALLD) that

NA

NA

NA

NA

detects leaks of three gallons per hour at ten pounds per square









inch line pressure within one hour; AND









HAR 11-280.1-44(1)









0A. Line tightness test: har 11-280.1-44(2)

YES

YES

NA

NA

0 Able to detect a 0.1 gph leak at 1 Yz times operating

YES

YES

NA

NA

Pressure; and









13 Line tightness test conducted every 365 days; OR

YES

YES

NA

NA

~ B. Monthly monitoring: har 11-280.1-43(7) to (9)

NA

NA

NA

NA

~ Able to detect a release from any portion of the

NA

NA

NA

NA

underground piping that routinely contains regulated









substances; and









~ Monitoring conducted at least every 30 days; OR

NA

NA

NA

NA

~ C. One or combination of methods listed in HAR 11-280.1-44(4)

NA

NA

NA

NA

Comments:

0.5 gph leak rate at 1 1/2 times operating pressure

MTC tank tightness test is third party certified by Ken Wilcox Associates.

Michael Baker International (Michael Baker) professional engineer certifies tank tightness test results.

Inspector's Name: S. BOBBY OJHA	02/28/22 -03/04/22

Page 61 of 97

Assisting Inspector, if any: RICK SAKOW

-------
HDOH ID 9-102771

survey OF RELEASE DETECTION METHODS for Pressurized Piping

List of Applicable Method, or Combination of Methods, of Release Detection

for Pressurized Piping

Pipeline
Outside Tunnel

Hydrant
Loops

HickamTruck
On-loading Racks

Kuahua Truck
On-loading Racks

D jnTSfstiti^lMonitoring

HAR 11-280.1-4317}"

D Statistical inventory reconciliaT

HAR 11-280.1-43(8)

~ Other method, or a combination of methods, that cand^t»jt^^T?gallon
per hour leak rate or a release of one hundred fifjjfcgtftfons withinlPmeQth
with a probability of detection of 0.95gpd-tf^robability of false alarm of
0.05; or the owner and opergiorCSndemonstrate to the department that
the method can deJgfiWrelease as effectively as any of the methods
allowed^»tHlTedepartment approves the method.

-43(9)

0 Performed semiannual or annual line tightness test at or above the piping
operating pressure in accordance with the table below:

HAR 11-280.1-44(4)1A)(i)

MAXIMUM LEAK DETECTION RATE PER TEST
SECTION VOLUME

YES

YES

NA

NA

Teal section vofcjme
(gallons)

Semiannual

test—leak
detection rale
not lo exceed
{gallons per
hour)

Annuel test—
leak detection
rale rot lo

exceed
(gallons par
hour)

<50.000		

1.0

05

250.000 to <75.000 	

1.5

075

275.000 to <100.000 	

2.0

1.0

2100.000		

30

1.5

~ Piping segment volumes >100,000 gallons not capable of meeting the
maximum 3.0 gallon per hour leak rate for the semiannual test may be
tested at a leak rate up to 6.0 gallons per hour according to the following
schedule:

HAR 11-280. l-44(4)(A)(ii)

PHASE IN FOR PIPING SEGMENTS
^100,000 GALLONS IN VOLUME

NA

NA

NA

NA

First test............... Not later than three years after the effective date

of these rules (may use up to 6.0 gph leak rate).

Second test	 Between three and six years after the effective

date of these rules (may use up to S.O gph leak

rate).

Third test 	- Between six and seven years after the effective

data of these rules (must use 3.0 gph for leak
rate).

Subsequent tests .. Not later than seven years after the effective
date of these rules, begin using semiannual or
annual line testing according to the Maximum
Leak Detection Rate Per Test Section Volume
table above.

NA
NA
NA
NA

NA
NA
NA
NA

NA
NA
NA
NA

NA
NA
NA
NA

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 62 of 97

-------
HDOH ID 9-102771

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 63 of 97

-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS For Pressurized Piping, As Applicable

~Vapor Monitoring ^Groundwater Monitoring Dnventory Control

*Ktepor Monitoring

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua f
Truck Op
LoadinfJRacks

§

W

assessment: Is applicable to system as installed, and documents
compliance with 11-280.1-43(5)(A-D), and kept for the life of the
methokL

HAR 11-280^^5(1)

~

~

~





Number/loaation of monitoring wells is established.

HAR 11-280.1-43(fy)

~

~





Backfill is sufficiently porous to allow migration of vapors.

HAR 11-280.1-43(5)(A)

~

~ j

~



Product (or tracer) i^ufficiently volatile to result in a vapor level that is
detectable by the momVoring devices located in the excavation zone.

HAR 11-280.1-43(5)(B)

~



~



Measurements of vapors b^je monitoring device is not rendered
inoperative by the groundwater rainfall, soil moisture or other known
interferences so that a release coc^d go undetected for more than 31
days.

HAR 11-280.1-43(S)(C)

u/

~

~



Level of background contamination will mrt interfere with
measurements/sampling. f

HAR 11-280.1-43(5)(D) X

~

~

~



System is designed and operated to detect any significant increase
concentration above background of the regulated sV^bstance stoj^a in
the tank system, a component or components of thatiubstanae, or a
tracer compound placed in the tank system

HAR 11-280.1-43(5)(E)

~

~

~



Wells are clearly marked and secured to avoid unautho^zed access and
tampering.

HAR 11-280.1-43(S)(G) X X

~

~

~



*Groundwater Monitoring f

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Rack

Kuahua
Truck On
Loading Rack

8

H

W

Site assessment: Is applicable to system a^mstalled, documents \
compliant with 11-280.1-43(6)(A-F), ancUestablishes number/location of
wells and kept for the life of the method.

HAR 11-280.1-43(6)(G) and HAR 11-280.1-45(1) f

\P

~

~





Wells are clearly marked and seared to avoid unauthorized access and
tampering.

HAR 11-280.1-43(6)(H) X

~ \

~

~



Product stored is immiscij/e in water and has specific gravity less than
one.

HAR 11-280.1-43(6)(A) X

~



~



Groundwater is njwer more than 20 feet from ground surface, and
hydraulic conductivity is greater than 0.01 cm/sec.

HAR 11-280.1-43^(8)

~

~





Slotted potion of well casing keeps surrounding soil or filter pack out of
well aiynsllows product to flow into well under high and low ground
watarconditions.

HABfll-280.1 -43(6)(C)

~

~

~



JNelis are sealed from ground surface to top of filter pack.

HAR 11-280.1-43(6)(D)

~

~

~



Inspector's Name: S. BOBBY OJHA 02/28/22-03/04/22
Inspector's Initial: 	

Assisting Inspector, if any: R|QK SAKOW

Page 64 of 97

-------
HDOH ID 9-102771

intercept the excavation zone or as close to excavation zone as is

technican^h^&Lble. har u-280.i-43(6)(E)

Equipment can detectat

HAR 11-280.1-43(6)(F)

inch of free product.

inventory Control AND Line Tightness Test PLUS Vap?
Groundwater Monitoring

Inventory is conducted in accordancewj£b»Bgpartment of Defense
Directive 4140.25, ATA AirogjS^W^TFacility Operations and Maintenance
Guidance ManugJ^requivalent procedures.

HAR II ||| I l|H|ll|l I

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua
Truck On
Loading Racks

Comments:

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 65 of 97

-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS For Pressurized Piping

General Requirements for All Pressurized Piping Using A Method, or A
Combination of Methods, of Release Detection

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua
Truck On
Loading Racks



Release detection can detect a release from any portion of the piping.

HAR ll-280.1-40(a)(l)

El

El

\ °



8
2

The release detection is installed, calibrated, operated and maintained in
accordance with the manufacturer's instructions, and routine service and
maintenance checks.

HAR 11-280. l-40(a)(3)

NA

NA





0

1

W

The release detection equipment is tested for proper operation at least
every 365 days or in a time frame recommended by the equipment
manufacturer, whichever is more frequent.

HAR 11-280.1 40(a)(4)

Dates of the last 3 tests: . and

NA

NA

~\





All maintenance and service of the release detection equipment are
conducted by a technician with current certification or training
appropriate to the equipment serviced.

HAR ll-280.1-40(a)(4)

Technician's Name: Exp. of training:

\z\

El

~ j



8

V>

The release detection equipment meets the performance requirements
specified for that method, har n-280.i-40(a)(S)

0 The release detection equipment is capable of detecting the leak

rate or quantity specified for that method.

El The probability of detection (Pd) of 0.95 and the probability of

false alarm (Pfa) of 0.05 are met.

171 Fill out Monthly (30-Day) Release Detection for Tanks and Piping
Table

~
El
El

El
El
El

D/





If release detection is not met, then completed change-in-service, or

Closure. HAR ll-280.1-40(c)

~

~

/ D



Recordkeeping

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua
Truck On
Loading Racks

o
o

rH

All written performance claims pertaining to any release detection
system used, and the manner in which these claims have been justified
or tested by the equipment manufacturer or installer, are maintained for
the operating life of the UST system.

HAR 11-280.1-45(1)

El

EI

\n



8

W

The results of any sampling, testing, or monitoring are maintained for at
least three (3) years.

HAR 11-280.1-45(2)

El

El

~ \



8

rH

V>

All records that the equipment being utilized to monitor or maintain the
UST system is designed to produce are maintained for at least three (3)
years after the records are generated.

HAR 11-280.1-45(3)

El

El

~ /



8

tH

1/V

Written documentation of all calibration, maintenance, and repair of
release detection equipment permanently located on-site are
maintained for at least three (3) years.

HAR 11-280.1-45(4)

El

El

/~



Comments:

Release detection datelines for pipelines (Attachment). Pipeline Petroleum Services, Inc. (PPSI), and
Hansa Consult of North America, LLC performed the pipeline tightness test.

Inspector's Name: S. BOBBY OJHA

Assisting Inspector, if any: RICK SAKOW

NA
NA

02/28/22 - 03/04/22

Page 66 of 97

-------
HDOH ID 9-102771

REPAIR REQUIREMENTS - Red Hill Facility (excluding PRTs)

I

Repairs to UST systems is properly conducted in accordance with a code of practice
developed by a nationally recognized association or an independent testing laboratory;

HAR ll-280.1-33(a)(l)

~ Yes Oslo DN/A



Repairs to fiberglass-reinforced plastic tanks was made by the manufacturer's authorized
representatives or in accordance with a code of practice developed by a nationally
recognized organization or an independent testing laboratory;

HAR 11-280. l-33(a)(2)

~ Yes DNo ElN/A



Metal pipe sections and fittings that have released product as a result of corrosion or other
damage were replaced. Non-corrodible pipes and fittings were repaired in accordance with
the manufacturer's specifications; har n-280.i-33(a)(3)

~ Yes O\lo 0N/A

8

Z

Prior to the return to use of a repaired UST system, any repaired USTs passed a tank
tightness test in accordance with section 11-280.1-43(3).

HAR 11-280. l-33(a)(4)

~ Yes ElNo ON/A



Prior to the return to use of a repaired UST system, any repaired piping that routinely
contains product passed a line tightness test in accordance with section 11-280.1-44(2).

HAR ll-280.1-33(o)(5)

~ Yes 0No DN/A



Prior to the return to use of a repaired UST system, repairs to secondary containment areas
of tanks and piping used for interstitial monitoring, containment sumps used for interstitial
monitoring of piping, and containment walls have the secondary containment tested for
integrity using vacuum, pressure, or liquid methods in accordance with requirements
developed by the manufacturer, a code of practice developed by a nationally recognized
association or independent testing laboratory, or requirements established by the
department;

HAR 11-280.l-33(a)(6)

~ Yes DNo 0N/A

S

CM
W

Within six months following the repair of any cathodically protected UST system, the
cathodic protection system was tested in accordance with section 11-280.1-31(2) and (3) to
ensure that it is operating properly; and

HAR 11-280.l-33(a)(7)

~ Yes UNo 0IM/A

8

-------
Hickam Product Recovery Tanks :
Diamond Head And Ewa

Page 68 of 97

-------
HDOH ID 9-102771

Product Recovery Tanks PRT Diamond Head & PRT Ewa

Tank Number

Tank No. PRT"DH

Tank No. PRT-Ewa



Status of Tank

Currently-ln-Use

Currently-ln-Use



Date of Installation

07/01/2010

05/01/2006



Estimated Capacity

2000

4000



Compartmentalized

NO

NO



Manifold

NO

NO



Substance Stored

Jet Fuel F-24

Jet Fuel F-24



Tank 1° Containment Material

Steel

Steel



Tank 2° Containment Material

Steel

Steel



Corrosion Protection

Impressed Current

Impressed Current



Piping 1° Containment Material

Steel

Steel



Piping 2° Containment Material

Lined Trench

Lined Trench



Method of Product Dispensing

Not Applicable

Not Applicable



Spill Prevention Equipment

Spill Bucket

N/A



Overfill Prevention Equipment 1

Overfill Alarm

Overfill Alarm



Overfill Prevention Equipment 2







Spill/Overfill, not required

25-gallon limited delivery







Release Detection (Tank)

Interstitial Monitoring

Interstitial Monitoring



Additional Tank RD, if any







Additional Tank RD, if any







Release Detection (Piping)

Line Tightness Test (0.5gph)

Line Tightness Test (0.5gph)



Additional Piping RD, if any







Additional Piping RD, if any







Automatic line leak
detector (ALLD) type, if any







ALLD serial number







Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 69 of 97

-------
HDOH ID 9-102771

Comments: Product Recovery Tanks PRT Diamond Head & PRT Ewa

Spill bucket testing needs to be done on PRT Ewa spill bucket.

There is no spill bucket on the Diamond Head PRT tank.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 70 of 97

-------
HDOH ID 9-102771

Facility Drawing/Diagram - Product Recovery Tanks PRT Diamond Head and PRT Ewa

Note: Include a drawing that shows the general layout of the facility. The drawing may include the following: nearby
facilities and/or buildings; indication of North/South direction; identification of streets, roads and nearby bodies of water, if
there's any, and location of all USTs and dispenser pumps identified by number/s consistent with the tank & dispenser
pump numbers on the current permit, if applicable.

Inspector's Name: g. Bobby Ojha
Assisting Inspector, if any: Rick SskOW

02/28/22 - 03/04/22
Page 71 of 97

-------
HDOH ID 9-102771

UST System Set-up and Alarm History Printouts - Product; Recover/ Tanks

		

No alarm history reports were available during the inspection.

Inspector's Name S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 72 of 97

-------
HDOH ID 9-102771

SPILL PREVENTION REQUIREMENTS - Product Recovery Tanks PRT Diamond Head and PRT Ewa

~ Exempt:

~	Alternative equipment approved by the department is used.

HAR11-280. l-20(d)(2)(A)

~	Transfers of no more than 25 gallons.

HAR 11-280. l-20(dJ(2)(B)

Tank PRT-DH

Tank PRT-Ewa



NA

NA



NA

NA



8

CO

w

Spill prevention equipment will prevent release of product to the

environment.

HAR 11-280. l-20(d)(l)(A)

NA

YES



8

W

~	Spill prevention equipment is double walled and monitored every 31-days;

HAR 11-280. l-35(a)(l)(A)

OR

~	Spill prevention equipment tested every 365 days.

HAR 11-280.l-35(aj(l)(B)

Date(s) of Services:

NA

NA



NA

0*0



8

tH

w

Maintain spill prevention equipment testing/monitoring/inspection records
for three years.

HAR ll-280.1-35(b)

NA

0



Comments Re: SPILL PREVENTION REQUIREMENTS - Product Recovery Tanks PRT Diamond Heac
Spill bucket testing is required on PRT-Ewa and has never been conducted prior tc

and PRT Ewa

) this inspection.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 73 of 97

-------
HDOH ID 9-102771

OVERFILL PREVENTION REQUIREMENTS - Product Recovery Tanks PRT Diamond Head and PRT Ewa

~ Exempt:

~	Alternative equipment approved by the department is used.

HAR11-280. l-20(d)(2)(A)

~	Transfers of no more than 25 gallons.

HAR 11-280. l-20(d)(2)(B)

Tank

Tank PRT-Ewa



NA

NA



NA

NA



8

m


Automatically shut off flow into the tank when the tank is no more that 95%
full.

HAR 11-280. l-20(d)(l)(B)(i)

NO

NO



8

m
w

Overfill alarm alerts the transfer operator when the tank is no more
than 90% full by triggering a high-level alarm.

HAR ll-280.1-20(d)(l)(B)(ii)

~ Sign clearly labeled ~ Alarm is visible ~ Alarm is audible

HAR 11-280. l-20(d)(4)

NO

NO



8

m
<~>

For flow restrictors installed before July 15,2018, must restrict flow thirty
minutes prior to overfilling.

HAR 11-280. l-20{dj(3)

NA

NA



8

CM
W

Overfill prevention equipment inspected every three years.

HAR 11-280. l-35(a}(3)

Current service date: Previous service date:

( NO





8

rH

W

Maintain overfill prevention equipment testing/inspection records for three
years.

HAR ll-280.1-35(b)

NA NA
~ i

1

Comments: OVERFILL PREVENTION REQUIREMENTS - Product Recovery Tanks PRT Diamond Head and PRT Ewa

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 74 of 97

-------
HDOH ID 9-102771

CORROSION PROTECTION REQUIREMENTS - Product Recovery Tanks PRT Diamond Head and PRT Ewa

A. UST Systems Not Requiring Corrosion Protection

system is constructed of fiberglass-reinforced plastic or non-corrodible material.

HAR^XiSO. 1 -20(b)(l) and HAR ll-280.1-20(c)(l)	

~ Tank is constructed of steel and clad or jacketed with a non-corrodible material.

HAR 11-280. l-20(b)(3)

~ UST system is constructechstfjietal without additional corrosion protection measures prj

HAR 11-280.l-20(b)(4) and HAR 11-280.1-.

~	UST system is installed at a site tFTa^determined by a corrosion exp^pfc-ftfSt to be corrosive enough to cause it to
have a release due to corrosion during itl^sp^rating life;

HAR 11-280.l-20(b)(4)(A) and HAR ll-280.1-20(c)(3)(A)

AND

~	Owners and operators maintain recordsfoafffemonstrate coftTpU^nce with the requirements that the UST system is
installed at the site that is detenrywtfCTby a corrosion expert to not be*Ca*£gsive enough to cause it to have a release
due to corrosion during it£j&f3£rating life.

	HAR 11-280. l-20(b)(4)(B) a^nKRl1-280.1-20(c)(3)(B)

~ The UST system c^twffuction and corrosion protection are determined by the department to beTtesigjied to prevent the
release orthrSatened release of any stored regulated substance in a manner that is no less protective ofPTttnaan health
an^Hfenvironment.

1AR ll-280.1-20(b)(5) and HAR ll-280.1-20(c)(4)	

B. UST Systems Requiring Cathodic Protection

13 UST system is constructed of steel and cathodically protected in the following manner:

HAR 11-280. l-20(b)(2)

El UST system is coated with a suitable dielectric material.

HAR 11-280. l-20(b)(2)(A)

13 Field-installed cathodic protection systems are designed by a corrosion expert.

HAR 11-280. l-20(b)(2)(B)

El Impressed current system are designed to allow determination of current operating status.

HAR ll-280.1-20(b)(2)(C)

m Cathodic protection systems are operated and maintained in accordance with section 11-280.1-31 or according to
guidelines established by the department.

	HAR 11-280. l-20(b)(2)(DI	

Operation and Maintenance of Corrosion Protection

All corrosion protection systems must be operated and maintained to continuously provide
corrosion protection to the metal components of that portion of the tank and piping that

routinely contain regulated substances and are in contact with the ground.

HAR 11-280.1-31(1)	

EI Yes DNo DN/A

Cathodic protection systems inspected for proper operation and by a qualified cathodic
protection (CP) tester as follows:

HAR 11-280.1-31(2)

Name of Qualified CP Tester:	 NACE Tech #:	

EI Yes DNo Dn/A

Frequency:

All CP systems must be tested within six (6) months of installation or repair and at
least every three (3) years thereafter;

HAR 11-280.1-31(2)(A)

AND

Inspection criteria:

The criteria that are used to determine that CP is adequate as required by this
section must be in accordance with a code of practice developed by a nationally
recognized association.

HAR 11-280.1-31(2)(B)	

El Yes DNo Dn/A

13 Yes DNo Dn/A

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 75 of 97

-------
HDOH ID 9-102771

Testing results from the last 2 inspections required for all CP systems maintained (tested
within 6 months after install or repair and at least every 3 years thereafter).

HAR 11-280.1-31(4)

Date of current CP inspection:	Date of previous CP inspection:	

El Yes DNo QN/A

Comments:

UST systems with impressed current CP systems inspected every sixty (60) days to ensure
the equipment is operating properly.

HAR 11-280.1-31(3)

Dates of last 3 inspections:	,	and	

~ Yes DNo ON/A

Current readings for impressed current systems
Amps:	 Volts:	 QN/A

Normal Range of Operation:

Comments Re: Product Recovery Tanks PRT Diamond Head and PRT Ewa

Documents were available at time of inspection.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 76 of 97

-------
HDOH ID 9-102771

LkAJhe containment sump is double-walled, documents showing that the equipment is
CT^yble walled, and the integrity of both walls is periodically monitored is

mainSyied. har n-280.i-35(b)(2)

CSIM

CSIM

CSIM

CSIM

CSIhf/

~

~

~



~

O
O

CM
W

The integrit^f both walls is periodically monitored at a frequency not less than
annually;

HAR ll-280.1-35(a)(2)(A)

Dates of periodic monitohae: . . and

~



~

~

~

CONTAINMENT sumps for interstitial monitoring (CSIM) requirements - Product Recovery Tanks

PRT Diamond Head and PRT Ewa

OR

A test is conducted within thirty (3C
double walled containment sump.

HAR ll-280.1-3S(a)(2)(A)	

ays of discontinuing periodic monitoring i

The repaired UST system component is tested appr

HAR 11-280.1 33(a)(6)

riately priorJ»^eturn to use.

Records of all testing or inspection are maintained forj

HAR ll-280.1-35(b)(l)

years.

~ B. The containment sump is single-walled.

The containment sump used for intej^Hfial monitoring is tested at least once
years in accordance with the manufacturer's instructions or a code of practice
developed by a nationally re^gnized association or independent testing laboratory.

HAR 11-280. l-35(a)(2)(B)

Date of current testia^T	Date of previous testing:

The repairedlUfff'system component is tested appropriately prior to return to use.

HAR ll-280.1jd(a)(6)

Reudfas of all testing or inspection are maintained for 3 years.

\R 11-280.l-35(b)(l)

Comments:

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 77 of 97

-------
HDOH ID 9-102771

UNDER DISPENSER CONTAINMENT (UDC) REQUIREMENTS - Product Recovery Tanks

PRT Diamond Head and PRT Ewa

AHS & FCT, dispenser system installed prior to July 15,
ZOla^a^e exempt from UDC requirements.

HAR ll-28bSy>5(a)	

~ Dispenser syKgm installed on or after August 9, 2013 must
be provided witmnn UDC.

HAR ll-280.1-25(b)

~	The UDC is liquicTHight on its sides, bottom, and at any
penetrations.

HAR 11-280.125(c)(1)

~	The UDC is compatible with rh^substanee conveyed

by the piping.

HAR 11-280.125(c)(2)

~	The UDC allows for visual inspection anchafcess to the

components in the containment system.
HAR 11-280.125(c)(3)

~	The UDC is monitored for leaks from the disMfiser
system with a sensing device that signak*Ke operator
of the presence of regulated substajj«^s.

	HAR ll-280.1-25(c)(4)

The sensing device is operated and maiflfained in accordance
with the manufacturer's instructionor a code of practice
developed by a nationally recognized association or
independent testing laboratory.

HAR ll-280.1-37(a)(l)

The sensing devices inspected for proper operation at least
every 365 davar -iarn-280.i-37(a)(2)

Testing djrfes:	,	, and

All w^fften documentation of inspection, testing, and

nntenance of the UDC sensing device are maintained for at
least 3 years? har u-280.i-37(b)

fication of Dispenser Serial Numbers: (Export information from the Dispenser Database)

Comments:

Inspector's Name: S. BOBBY OJHA	02/28/22 to 03/04/22

Dini/ cAi/oiAi	Page78of97

Assisting Inspector, if any: RICK SAKOW

-------
HDOH ID 9-102771

PERIODIC OPERATION AND MAINTENANCE WALKTHROUGH INSPECTION REQUIREMENTS

	Product Recovery Tanks PRT Diamond Head and PRT Ewa	

The periodic operation and maintenance walkthrough inspections for Spill Prevention
Equipment and Release Detection Equipment are conducted every 31 days, har n-280.i-36(a)(i)

A.	Spill prevention equipment: harn-280.i-36(a)(i)(A)

13 Visually check for damage

~	Remove liquid or debris

IZ1 Check for and remove obstructions in the fill pipe
13 Check the fill cap to make sure it is securely on the fill pipe

~	For doubled-walled (DW) spill prevention equipment with interstitial monitoring,
check for a leak in the interstitial area.

B.	Release detection equipment: harn-28o.i-36(a)(i)(B)

~	Check to make sure the release detection equipment is operating with no alarms
or other unusual operating conditions present

~	Records of release detection testing are reviewed and current

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 79 of 97

-------
HDOH ID 9-102771

The periodic operation arid maintenance walkthrough inspection for containment sumps
used for interstitial monitoring of piping and handheld release detection equipment are
conducted every 365 days.

HAR 11-280. l-36(a)(2)

A.	Containment sumps:

HAR ll-280.1-36(a)(2)(A)

~	Visually check for damage, leaks to the containment area, or releases to the
environment

O Remove liquid (in contained sumps) or debris

~	For DW sumps with interstitial monitoring, check for a leak in the interstitial area

B.	Hand held release detection equipment: Q check devices such as tank gauge sticks or
groundwater bailers for operability and serviceability.

HAR ll-280.1-36(a)(2)(B)

Dates of annual (365 days) inspections:	,	and	

FbsUST systems receiving deliveries at intervals greater than every 31 days, the spill
prevemiqn equipment is checked prior to each delivery.

HAR ll-280.1^d)(3)

~ Yes DNo ElN/A

PeriocfiN^nd M
Deliveries ATtq,

aintenance Walkthrough
ervals Greater Than Ever

nspections For UST Si
y 31 Days (e.g. Emergj

,fstem>^eceiving
y*€y Generators)

Delivery Dates

Tiate of Inspection

X

Delivery Date^^^

Date of Inspection





























\



























































~ Yes DNo IZlN/A

When confined space entry IS NOT required by OSHA for Airport Hydrant System (AHS),
hydrant pits and hydrant piping vaults, if any, are periodically checked every 31 days.

HAR ll-280.1-36(a)(4)	

~ Yes Oslo ElN/A

When confined space entry IS required by OSHA for AHS, hydrant pits and hydrant piping
vaults, if any, are periodically checked annually.

HAR 11-280. l-36(a)(4)	

~ Yes DNO ElN/A

Records of the monthly (31 days) and annual (365 days) operation and maintenance
walkthrough inspections are maintained for 3 years.

HAR ll-280.1-36(b)	

El Yes O\lo ON/A

Comments:

Documents were available at time of inspeciton.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 80 of 97

-------
HDOH ID 9-102771

I. RELEASE DETECTION REQUIREMENTS FOR TANKS - Product Recovery Tanks PRT Diamond Head and PRT Ewa

General Requirements for All Tanks Using A Method, or A Combination of Methods, Listed Below

~ Inventory Control (C) ~ Manual Tank Gauging (MTG) DTank Tightness Testing (TTT)
El Interstitial Monitoring (IM) ~ Automatic Tank Gauging (ATG)

Tank

PRT-DH

Tank

PRT-Ewa



£

Release detection can detect a release from any portion of the UST.

HAR ll-280.1-40(a)(l) \

NO

NO

>

l

The release detection is installed, calibrated, operated and maintained in accordance with the
manufacturer's instructions, and routine service and maintenance checks.

HAR 11-280. l-40(a)(3)

NA

NA





The release detection equipment is tested for proper operation at least every 365 days or in a

time frame recommended by the equipment manufacturer, whichever is more frequent.

HAR 11-280.140(a)(4)

Dates of the last three (3) tests: . and

NA

NA



O

St

All maintenance and service of the release detection equipment are conducted by a
technician with current certification or training appropriate to the equipment serviced.

HAR 11-280.140(a)(4)

Technician's Name: Exp. of Training:

YES

YES



8

The release detection equipment meets the performance requirements specified for that
method. HAR ll-280.1-40(a)(5)

~	The release detection equipment is capable of detecting the leak rate or quantity
specified for that method.

~	The probability of detection (Pd) of 0.95 and the probability of false alarm (Pfa) of
0.05 are met.

~	Fill out Monthly (31-Day) Release Detection for Tanks and Piping Table

NA

NA





If release detection requirements are not met, then completed change-in-service, or closure.

HAR 11-280.140(c)

NA

NA



Recordkeeping

PRT-DH

PRT-Ewa



O
O

T-H

w

All written performance claims pertaining to any release detection system used, and the
manner in which these claims have been justified or tested by the equipment manufacturer
or installer, are maintained for the operating life of the UST system, har u-280.i-4S(i)

NA

NA



8

rH
W

The results of any sampling, testing, or monitoring are maintained for at least three (3) years.

HAR 11-280.1-45(2)

NA

NA



8

T-H

w

All records that the equipment being utilized to monitor or maintain the UST system is
designed to produce are maintained for at least three (3) years after the records are
generated.

HAR 11-280.1-45(3)

YES

YES



8

rH

W

Written documentation of all calibration, maintenance, and repair of release detection
equipment permanently located on-site are maintained for at least three (3) years.

HAR 11-280.1-45(4)

NA

NA



Comments:





Is there a sensor within the interstitial space within both tanks? Ask HDOH





Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 81 of 97

-------
HDOH ID 9-102771

Tank Release Detection Methods - Product Recovery Tanks PRT Diamond Head and PRT Ewa

Inventory Control

Tank

PRT-DH

Tank

PRT-Ewa

Product inventory control is conducted every 31 days to detect a release of at least 1% flow
tnhHigh plus 130 gallons.

HAR ll-2lfcs*43(l]	

~

The daily tanklTi|Hi^level measurements are recorded.

HAR 11-280.1-43(1)(A)

~

The equipment is capable ofma^suring to l/8th inch accuracy in tank liquid^etfel
measurements.

HAR 11-280.1-43(1)(B)	

Gauging Device: measurements made througny*Qp tube,	extends to within one foot of

bottom of tank (i.e., manual device only), and readin^fcgfcen to the nearest 1/8^ inch.

HAR 11-280.1-43(1)(C)	

Before and after delivery, the tank liquid lev^J*measurements ar&H^conciled with volume
according to delivery receipt.

HAR 11-280.1-43(1J(DJ	

~

The drop tube present in tapkfiil pipe is within one foot of tank bottom.

HAR 11-280.1-43(1)(E)

The dispenserp»«er is calibrated.

HAR 11-280. l-A*ff)(F)

Cjjs^for water to l/8th inch accuracy is conducted every month.

HAR 11-280.1-43(1)(G)

Manual Tank Gauging (MTG)

Tank

PRT-DH

Tank

PRT-Ewa

lominal capacity is 2,000 gallons or less and if tank tightness test is applicable.

H%k%L280.1-43(2)(F)

OperationSqd maintenance of MTG is every 31 days.

HAR 11-280.1-45(21*

MTG is conducted for&fapropriate time period (test duration according to standard list in
table), during which no liquTfck^added to or removed from the tank.

HAR 11-280.1-43(2)(A)	

Nominal tank capacity

Minimum durjjjdfi

Weekly Standard
(one test)

Monthly Standard
(four test Average)

550 gallons or less



10 gallons

5 gallons

551-1,000 gallons (when tank diameter is 64 Inches)

44 hours^^^.

9 gallons

4 gallons

551-1,000 gallons (when tank diameter is 48 inches)^^^^

58 hours

12 gallons

6 gallons

551-1,000 gallons (also requires periodic tanl^Ngntness testing)

36 hours

13 gallons

7 gallons

1,000-2,000 gallons (also require periodic tank tightness testing)

36 hours

2^t4|ons

13 gallons

Note: Weekly measuremenj^t^fcen, and if five weeks in the month, then the weekly test with smallest discrepancy is not^^^^^

Gauging dpwTfe: Measurements taken through drop tube (for manual device), and readings
takej>*o nearest l/8th inch, and within one foot of tank bottom.

11-280.1-43(2)(B)

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 82 of 97

-------
HDOH ID 9-102771



¦Readings are based on average of two stick readings taken at both the beginning and ending
ofths^ime period.

HAR ll-28lh+4g(2)(C)

~

~



The equipmenrbs^d is capable of measuring to l/8th inch accuracy.

HAR 11-280.1-43(2)(DJ

~





Variation between beginnin^^d ending measurements is checked against weekly and
monthly standards in table, and ctet^nnination is made whether a release is suspected^"^

HAR 11-280.1-43(2)(E)

~

~



Tank Tightness Testing (III)

Tank

PRT-DH

Tank

PRT-Ewa





Able to detect a 0.1 gallon per hour (gph) leak rate from am^gftion of the tank that routinely
contains product while accounting for the effects ofjb^fmal expansion or contraction of the
product, vapor pockets, tank deformation, e^f>6ration or condensatiorvSHjdthe location of
the water table, har 11-280.1-43(3)

Dates of the last 3 TTT:

~

~



Automatic Tank Gaugjpg^ATG)

^Tank

Tank

PRT-Ewa



I

Detect^st
-------
HDOH ID 9-102771

II. RELEASE DETECTION REQUIREMENTS FOR PIPING PER METHOD OF PRODUCT DISPENSING

Product Recovery Tanks - PRT Diamond Head and PRT Ewa



Method of Product Dispensing

Piping

Piping



~ Safe I~1 Unsafe Suction 0 Pressurized

PRT-DH

PRT-Ewa



DSafe Suction: Exempt from release detection if ALL the requirements listed below are met:

~





CHjhe below-grade piping operates at less than atmospheric pressure.



~



H>mil-280.1-41(b)(6)(A)





~ The 0s|ow-grade piping slopes uniformly back to the tank.

~

~



HAR ll-2mS^l(b)(6)(B) S



~ There is onlySqe check valve in each section line. yr







HAR ll-280.1-41(b)(6fttHL

~

~



~ The check valve is looted directly below and as close as practicable to the s^fion pump.







HAR 11-280.l-41(b)(6)(D)







~ Compliance with above specifications can be readily determined, yr

~

~



HAR 11-280. l-41(b)(6)(E)







~ Unsafe Suction Piping: If Unsafe Suction piping/ttjen leak deJ/e£tion must be provided as

~

~



follows:







HAR ll-280.1-41(b)







~ A. Line tightness test (0.1 gph)

~

~



~ Line tightness test conducted eyefy 3 years X*.

~

~



~ Able to detect 0.1 gph at l^Times operating pressure; OHw

~

~



~ B. Perform one of the followjrfgmonthly monitoring methods: (USEYHE APPROPRIATE

~

~



CHECKLIST) X.







~ Interstitial mpfritoring

~

~



~ 0.2 gph tightness testing method \

~

~



~ VaMl^monitoring

~

~



~groundwater monitoring

~



.~""O Statistical inventory reconciliation

~





~ Pressurized Piping: MUST be provided with an automatic line leak detector (ALLD) AND either:







El A. Line tightness test (0.1 gph)







0 Able to detect a 0.1 gph leak at 1 Yi times operating pressure

Yes

Yes



[71 Line tightness test conducted every 365 days; OR

Yes

Yes



~ B. Perform one of the following monthly monitoring methods: (USE THE APPROPRIATE







CHECKLIST)

N/A

N/A



~ Interstitial monitoring

N/A

N/A



~ o.2 gph line tightness testing method

N/A

N/A



~ Vapor monitoring

N/A

N/A



~ Groundwater monitoring

N/A

N/A



~ Statistical inventory reconciliation

N/A

N/A



Comments:





Appears to be using Line Tightness Test (LTT) performed annually for the sections of piping run that are

underground between the tank and the pump house.





The product in the product piping goes back into the large ASTs within the Hickam AST farm.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 84 of 97

-------
HDOH ID 9-102771

III. RELEASE DETECTION REQUIREMENTS FOR PIPING - Product Recovery Tanks

PRT Diamond Head and PRT Ewa

General Requirements for All Piping Using A Method, or A Combination of Methods, Listed Below



Applicable release detection method, or combination of methods, is provided.

~ Interstitial Monitoring:

Designed, constructed, and installed to detect a leak from any portion of the piping, and a
double walled system that can detect a release through the inner wall, har 11-280.1-43(7)

PRT-DH

PRT-Ewa













YES

YES





__

~ Line Tightness Testing (0.2):

Able to detect a 0.2 gph leak rate with a 0.95 Pd and 0.05 Pfa. har 11-280.1-43(9)









YES

YES















Release detection can detect a release from any portion of the piping.

HAR 11-280.1-40(a)(1)

YES

YES



o

a

The release detection is installed, calibrated, operated and maintained in accordance with the
manufacturer's instructions, and routine service and maintenance checks.

HAR 11-280.l-40(a) (3)

NA

NA



¦s-

The release detection equipment is tested for proper operation at least every 365 days or in a
time frame recommended by the equipment manufacturer, whichever is more frequent.

HAR 11-280.1 40(a)(4)

Dates of the last 3 tests: . and

NA

NA



8

2

All maintenance and service of the release detection equipment are conducted by a
technician with current certification or training appropriate to the equipment serviced.

HAR ll-280.1-40(a)(4)

Technician's Name: Exd. of training:

NA

NA





The release detection equipment meets the performance requirements specified for that
method. HAR ll-280.1-40(a)(5)

~	The release detection equipment is capable of detecting the leak rate or quantity
specified for that method.

~	The probability of detection (Pd) of 0.95 and the probability of false alarm (Pfa) of
0.05 are met.

~	Fill out Monthly (31-Day) Release Detection for Tanks and Piping Table

NA

NA
NA

NA

NA
NA





If release detection is not met, then completed change-in-service, or closure.

HAR ll-280.1-40(c)

NA

NA



Recordkeeping







8

rH

w

All written performance claims pertaining to any release detection system used, and the
manner in which these claims have been justified or tested by the equipment manufacturer
or installer, are maintained for the operating life of the UST system.

HAR 11-280.1-45(1)

NA

NA



8

W

The results of any sampling, testing, or monitoring are maintained for at least three (3) years.

HAR 11-280.1-45(2)

NA

NA



8

rt
W

All records that the equipment being utilized to monitor or maintain the UST system is
designed to produce are maintained for at least three (3) years after the records are
generated.

HAR 11-280.1-45(3)

NA

NA



8

rH

W

Written documentation of all calibration, maintenance, and repair of release detection
equipment permanently located on-site are maintained for at least three (3) years.

HAR 11-280.1-45(4)

NA

NA



Comments:

Where does the liquid from PRT tanks go once they get full. Is there piping? We need clarification.

Navy needs to confirm and submit the valid release detection method for the piping associated with the PRTs, including any 3rd party certifications,
full report of test results, 31-day release detection monitoring.

Is the system a suction system since we didn't see a turbine sump. The pump house has jet fuel piping to the emergency generator and it appears to
be underground piping, which we didn't see. Is it pressurized/suction?

Inspector's Name: S. BOBBY OJHA	02/28/22 to 03/04/22

~Page85of97
Assisting Inspector, if any: RICK SAKOW

-------
HDOH ID 9-102771

iv. RELEASE detection requirements for all other methods - Product Recovery Tanks

PRT Diamond Head and PRT

General Requirements for All Other Methods
Vapor Monitoring (VM), Groundwater Monitoring (GWM) and Statistical Inventory Reconciliation (SIR)

Recordkeeping

PRT-DH

PRT-Ewa

Tanks installed before August 9, 2013 must be monitored for releases at least every 31 days PRT-DH PRT-Ewa
sing one of the methods listed in section 11-280.1-43(4) to (9) except,

HmS^280.1-41(a)(1)(A)

[AJST systems meet performance standards in section 11-280.1-20, and the monthly
in^ntory control requirements in section 11-280.1-43(1) or (2), may use tank
tightness testing at least every 5 years until 10 years after the tank was installed;

HAR ll-280tsi(a)(l)(A)(i)

AND

~ Tanks with capact\of 550 gallons or less and tanks with a capacity of 551 to 1,Q£
gallons that meet theS^nk diameter criteria in section 11-280.1-43(2) may i
manual tank gauging. HAlS^280.i-4i(a)(i)(A)(ii)

If release detection requirements canr
or closure procedures, har ii-280.i-40(c)

be met, then must complete the chrfnge-in-service

Release detection can detect a release from anv

HAR ll-280.1-40(a)(l)

lortion of the USTx^stem.

The release detection is installed, calibrated, operated
manufacturer's instructions, and routine service and i
Dates of the last 3 tests:	

faintained in accordance with the
jnce checks, har n-280.i-40(a)(3)

and	

The release detection equipment is tested forproper operation at le&§t every 365 days or in a
time frame recommended by the equipmj^ffimanufacturer, whichever iSs^ore frequent.

HAR 11-280. l-40(a)(4)	

All maintenance and service of the^Tease detection equipment are conductecnsw a
technician with current certification or training appropriate to the equipment servic

HAR 11-280.1-40(a) (3)

Technician's Name: /	Exp, of training:

The release detection equipment meets the performance requirements specified for that
method, har iij0tTi-4O(a)(5)

~	Th^elease detection equipment is capable of detecting the leak rate or quantity
Specified for that method.

[The probability of detection (Pd) of 0.95 and the probability of false alarm (Pfa) of
0.05 are met

~	Fill out Monthly (31-Day) Release Detection for Tanks and Piping Table

i/ritten performance claims pertaining to any release detection system used, and the
mannerfTTwhi^hthese claims have been justified or tested by the equipment manufacturer
or installer, are manTtsmje^for the operating life of the UST system.

HAR 11-280.1-45(1)	

The results for any sampling, testing, or m?

HAR 11-280.1-45(2)

jng are maintained

least three years.

All records that the equipment being utilizedJe-fitCnTtor or mainTShvttaUST system is
designed to produce are maintajrjgd-ftJfatleast three years after the recom5>f««eenerated.

HAR 11-280.1-45(3)	

Written docujjjflfrtSfTon of all calibration, maintenance, and repair of release detection
ej^j^ipmgntpermanently located on-site are maintained for at least three years.

HAR 11-280.1-45(4)	

Comments:

Inspector's Name: S. BOBBY OJHA	02/28/22 to 03/04/22

Page86of97

Assisting Inspector, if any: RICK SAKOW

-------
HDOH ID 9-102771

System

'RT-Ewa

^EASE DETECTION REQUIREMENTS FOR ALL OTHER METHODS - Product Recovery Tanks PRT Diamond Head and PF
~Vapor Monitoring	~Groundwater Monitoring	~Statistical Inventory Reconciliation (SIR)

Vapor Monitor?!

Site assessment: f5*amjlicable to system as installed, and documents compliance with 11-
280.1-43(5)(A-D), andRfeui for the life of the method.

HAR 11-280.1-45(1)	

Number/location of monitoring^

HAR 11-280.1-43(5J(F)	

ills is established.

Backfill is sufficiently porous to allow migtat^on of vapors.

HAR 11-280.1-43(5)(A)	

Product (or tracer) is sufficiently volatile to result!
monitoring devices located in the excavation zone.

HAR 11-280.1-43(5)(B)

vapor leveWnat is detectable by the

Measurements of vapors by the monitoring devicp^fTnot render&4
-------
HDOH ID 9-102771

Statistical Inventory Reconciliation (SIR)

UST
System

PRT-DH

UST
System

PRT-Ewa



I

"TTTmtriry j" rnnHnrtrH according to provider's specifications.

HAR " | 1 —

~	Report a |ii inlil ill i i Mil 	illi ,| i il ill ill 1 leak rate.

HAR 11-280.1-43(8)(A)

~	Capable of detecting a leak i il i,if fl "i ri'lT'1' M'l 1 '" ' "'H (' ,'Hi ill i 11 ii 11 31 days.

HAR -- •">" «

[~] 1 |"ffi 11+rrr'nnln tlrit does not exceed one-half the minimum detectible leak rate.

HAR 11-280.1-43(8)(B)

~
~

D
~



Co

mments:







Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 to 03/04/22

Page 88 of 97

-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS - Surge Tanks F-ST1 to F-ST4

General Requirements for All Tanks Using A Method, or A Combination of
Methods, of Release Detection

F-ST1

F-ST2

F-ST3

F-ST4

8

-------
HDOH ID 9-102771

SURVEY OF RELEASE DETECTION FOR PIPING Per Method of Product Dis

pensing

Method of Product Dispensing

Pipeline

Hydrant

Hickam
Truck On

Kuahua
Truck On

~ Safe ~ Unsafe Suction 0 Pressurized

Outside Tunnel

Loops

Loading Racks

Loading Racks

"QSafe Suction: Exempt from release detection if ALL the requirements listed

~

~

~



belovtox^re met:









~ Tha^below-grade piping operates at less than atmospheric pressure.

~

~





HAR ll^>9()J-41(b)(6)(A)









~ The below^f^de piping slopes uniformly back to the tank.

~







HAR 11-280. l-41(bj(Sjtel









~ There is only one cn^sl^alve in each section line.

~



~



HAR 11-280.l-41(b)(6)(C)









~ The check valve is located direbtly below and as close as practicable



~

~



to the suction pump. ^









HAR 11-280.l-41(b)(6)(D)









~ Compliance with above specifications can be>«adily detenjwrfed.

~

~

~



HAR ll-280.1-41(b)(6)(E)









~ Unsafe Suction Piping: If Unsafe Suction piping, then le^J^oefcaQtion must

~

~

~



be provided as follows:









HAR 11-280.l-41{b)









~ A. Line tightness test (0.1 gph)









~ Line tightness test conjUrfted every 3 years



~

~



~ Able to detect O-J^fSn at 1 Yi times operating pressure; OR



~

~



~ B. Perform one of^ke Following monthly monitoring methods:









l~l IntersJifci^T monitoring

~



~



~ Q^gph line tightness testing method

~

~





~ Vapor monitoring

~

~





~ Groundwater monitoring

~

~

~



S* ~ Statistical inventory reconciliation

~

~

~



171 Pressurized Piping:

N/A

N/A

N/A

N/A

~ Must be provided with an automatic line leak detector (ALLD) that

N/A

N/A

N/A

N/A

detects leaks of three gallons per hour at ten pounds per square

inch line pressure within one hour; AND









HAR 11-280.1-44(1)









0A. Line tightness test: har 11-280.1-44(2)

Yes

Yes

N/A

N/A

0 Able to detect a 0.1 gph leak at 1 Yz times operating

Yes

Yes

N/A

N/A

Pressure; and









13 Line tightness test conducted every 365 days; OR

Yes

Yes

N/A

N/A

~ B. Monthly monitoring: har 11-280.1-43(7) to(9)









~ Able to detect a release from any portion of the

N/A

N/A

N/A

N/A

underground piping that routinely contains regulated









substances; and









~ Monitoring conducted at least every 30 days; OR

N/A

N/A

N/A

N/A

~ C. One or combination of methods listed in HAR 11-280.1-44(4)

N/A

N/A

N/A

N/A

Comments:

Inspector's Name: S. BOBBY OJHA	02/28/22 -03/04/22

Page 90 of 97

Assisting Inspector, if any: RICK SAKOW

-------
HDOH ID 9-102771

survey OF RELEASE DETECTION METHODS for Pressurized Piping

List of Applicable Method, or Combination of Methods, of Release Detection

for Pressurized Piping

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua
Truck On
Loading Racks

D IntSTHitigJMonitoring

HAR 11-280.1-43(7]'

D Statistical inventory reconcile

HAR 11-280.1-43(8)

~ Other method, or a combination of methods, that can a^Ttejfc^^Tgallon
per hour leak rate or a release of one hundred fift}i«gtrtf5ns within5"Tn«Qjh
with a probability of detection of 0.95aijfiKprobability of false alarm of
0.05; or the owner and opergJf>pcSndemonstrate to the department that
the method can deJefi*^Telease as effectively as any of the methods
allowedjjMKRedepartment approves the method.

fT43(9)

0 Performed semiannual or annual line tightness test at or above the piping
operating pressure in accordance with the table below:

HAR 11-280.1-44(4)1A)(i)

MAXIMUM LEAK DETECTION RATE PER TEST
SECTION VOLUME

N/A

N/A

N/A

N/A

Teal section vofcjme
(gallons)

Semiannual

test—leak
detection rale
not lo exceed
{gallons per
hour)

Annuel test—
leak detection
rale rot lo

exceed
(gallons par
hour)

<50.000		

1.0

05

250.000 to <75.000 	

1.5

075

275.000 to <100.000 	

2.0

1.0

2100.000		

30

1.5

~ Piping segment volumes >100,000 gallons not capable of meeting the
maximum 3.0 gallon per hour leak rate for the semiannual test may be
tested at a leak rate up to 6.0 gallons per hour according to the following
schedule:

HAR 11-280. l-44(4)(A)(ii)

PHASE IN FOR PIPING SEGMENTS
^100,000 GALLONS IN VOLUME

N/A

N/A

N/A

N/A

First test............... Not later than three years after the effective date

of these rules (may use up to 6.0 gph leak rate).

Second test	 Between three and six years after the effective

date of these rules (may use up to S.O gph leak

rate).

Third test 	- Between six and seven years after the effective

data of these rules (must use 3.0 gph for leak
rate).

Subsequent tests .. Not later than seven years after the effective
date of these rules, begin using semiannual or
annual line testing according to the Maximum
Leak Detection Rate Per Test Section Volume
table above.

N/A
N/A
N/A

N/A

N/A
N/A
N/A

N/A

N/A
N/A
N/A

N/A

N/A
N/A
N/A

N/A

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 91 of 97

-------
HDOH ID 9-102771

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 92 of 97

-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS For Pressurized Piping, As Applicable

~Vapor Monitoring ^Groundwater Monitoring Dnventory Control

*\apor Monitoring

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua y
Truck Oor
Loadin^Racks

§

W

Sfte assessment: Is applicable to system as installed, and documents
compliance with 11-280.1-43(5)(A-D), and kept for the life of the
methofcL

HAR 11-28^45(1)

~

~

~





Number/location of monitoring wells is established.

HAR 11-280.1-43 fiXf)

~

~





Backfill is sufficiently porous to allow migration of vapors.

HAR 11-280.1-43(5)(A) \

~

~ y

~



Product (or tracer) insufficiently volatile to result in a vapor level that is
detectable by the moniWing devices located in the excavation zone.

HAR 11-280.1-43(5)(B)

~



~



Measurements of vapors by\he monitoring device is not rendered
inoperative by the groundwater rainfall, soil moisture or other known
interferences so that a release cobki go undetected for more than 31
days.

HAR 11-280.1-43(5)(C) \

~/

~

~



Level of background contamination will nW interfere with
measurements/sampling. /

HAR 11-280.1-43(5)(D) /

~

~

~



System is designed and operated to detect any sWiificant increase i/T
concentration above background of the regulated substance stor«l in
the tank system, a component or components of thatVibstanpe, or a
tracer compound placed in the tank system

HAR 11-280.1-43(5)(E) )\

~

~

~



Wells are clearly marked and secured to avoid unauthorized access and
tampering. f

HAR 11-280.1-43(S)(G) / \

~

~

~



*Groundwater Monitoring / \

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua
Truck On
Loading Racks

8

H

W

Site assessment: Is applicable to system as/fistalled, documents >
compliant with 11-280.1-43(6)(A-F), and/establishes number/location of
wells and kept for the life of the method.

HAR 11-280.1-43(6)(G) and HAR 11-280.1-45(1) /

\p

~

~





Wells are clearly marked and seciffred to avoid unauthorized access and
tampering. /

HAR 11-280.1-43(6)(H) /

~ \

~

~



Product stored is immiscljrffe in water and has specific gravity less than
one. f

HAR 11-280.1-43(6)(A) /

~



~



Groundwater is npver more than 20 feet from ground surface, and
hydraulic conchrctivity is greater than 0.01 cm/sec.

HAR ll-280.1-43j/)(B)

~

~

\n



Slotted ponion of well casing keeps surrounding soil or filter pack out of
well an^Tallows product to flow into well under high and low ground
water:onditions.

HA Vni -280.1-43(6)(C)

~

~

~



JweWs are sealed from ground surface to top of filter pack.

HAR 11-280.1-43(6)(D)

~

~

~



Inspector's Name: S. BOBBY OJHA 02/28/22-03/04/22
Inspector's Initial: 	

Assisting Inspector, if any: R|QK SAKOW

Page 93 of 97

-------
HDOH ID 9-102771

[sintercept the excavation zone or as close to excavation zone as is
technicaTlV^®*5ible. har ii-280.i-43(6)(E)

Equipment can detect at

HAR 11-280.1-43(6)(F)

8 inch of free product.

inventory Control AND Line Tightness Test PLUS Vapc
Groundwater Monitoring

Inventory is conducted in accordancewjlk-Bepartment of Defense
Directive 4140.25, ATA Airpgft-ftJSTFacility Operations and Maintenance
Guidance Manug]<«r"Squivalent procedures.

HAR U-2W**ft{3j(C)

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua
Truck On
Loading Racks

Comments:

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 94 of 97

-------
HDOH ID 9-102771

RELEASE DETECTION REQUIREMENTS For Pressurized Piping

General Requirements for All Pressurized Piping Using A Method, or A
Combination of Methods, of Release Detection

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua
Truck On
Loading Racks



Release detection can detect a release from any portion of the piping.

HAR ll-280.1-40(a)(l)

YES

YES

YES

YES

8
2

The release detection is installed, calibrated, operated and maintained in
accordance with the manufacturer's instructions, and routine service and
maintenance checks.

HAR 11-280. l-40(a)(3)

NA

NA

NA

NA

0

1

W

The release detection equipment is tested for proper operation at least
every 365 days or in a time frame recommended by the equipment
manufacturer, whichever is more frequent.

HAR 11-280.1 40(a)(4)

Dates of the last 3 tests: . and

YES

YES

YES

YES



All maintenance and service of the release detection equipment are
conducted by a technician with current certification or training
appropriate to the equipment serviced.

HAR ll-280.1-40(a)(4)

Technician's Name: Exp. of training:

YES

YES

YES

YES

8

V>

The release detection equipment meets the performance requirements
specified for that method, har n-280.i-40(a)(S)

0 The release detection equipment is capable of detecting the leak

rate or quantity specified for that method.

[3 The probability of detection (Pd) of 0.95 and the probability of

false alarm (Pfa) of 0.05 are met.

171 Fill out Monthly (30-Day) Release Detection for Tanks and Piping
Table

YES
YES

YES

YES
YES

YES

YES
YES

YES

YES
YES

YES



If release detection is not met, then completed change-in-service, or

Closure. HAR ll-280.1-40(c)

NA

NA

NA

NA

Recordkeeping

Pipeline
Outside Tunnel

Hydrant
Loops

Hickam
Truck On
Loading Racks

Kuahua
Truck On
Loading Racks

o
o

rH

All written performance claims pertaining to any release detection
system used, and the manner in which these claims have been justified
or tested by the equipment manufacturer or installer, are maintained for
the operating life of the UST system.

HAR 11-280.1-45(1)

YES

YES

YES

YES

8

W

The results of any sampling, testing, or monitoring are maintained for at
least three (3) years.

HAR 11-280.1-45(2)

YES

YES

YES

YES

8

rH

V>

All records that the equipment being utilized to monitor or maintain the
UST system is designed to produce are maintained for at least three (3)
years after the records are generated.

HAR 11-280.1-45(3)

YES

YES

YES

YES

8

tH

W

Written documentation of all calibration, maintenance, and repair of
release detection equipment permanently located on-site are
maintained for at least three (3) years.

HAR 11-280.1-45(4)

YES

YES

YES

YES

Comments:

Release detection datelines for pipelines (Attachment). Pipeline Petroleum Services, Inc. (PPSI), and
Hansa Consult of North America, LLC performed the pipeline tightness test.

Inspector's Name: S. BOBBY OJHA
Assisting Inspector, if any: RICK SAKOW

02/28/22 - 03/04/22

Page 95 of 97

-------
HDOH ID 9-102771

REPAIR REQUIREMENTS - Red Hill Facility (excluding PRTs)

I

Repairs to UST systems is properly conducted in accordance with a code of practice
developed by a nationally recognized association or an independent testing laboratory;

HAR ll-280.1-33(a)(l)

~ Yes Oslo DN/A



Repairs to fiberglass-reinforced plastic tanks was made by the manufacturer's authorized
representatives or in accordance with a code of practice developed by a nationally
recognized organization or an independent testing laboratory;

HAR 11-280. l-33(a)(2)

~ Yes DNo ElN/A



Metal pipe sections and fittings that have released product as a result of corrosion or other
damage were replaced. Non-corrodible pipes and fittings were repaired in accordance with
the manufacturer's specifications; har n-280.i-33(a)(3)

~ Yes O\lo 0N/A

8

Z

Prior to the return to use of a repaired UST system, any repaired USTs passed a tank
tightness test in accordance with section 11-280.1-43(3).

HAR 11-280. l-33(a)(4)

~ Yes ElNo ON/A



Prior to the return to use of a repaired UST system, any repaired piping that routinely
contains product passed a line tightness test in accordance with section 11-280.1-44(2).

HAR ll-280.1-33(o)(5)

~ Yes 0No DN/A



Prior to the return to use of a repaired UST system, repairs to secondary containment areas
of tanks and piping used for interstitial monitoring, containment sumps used for interstitial
monitoring of piping, and containment walls have the secondary containment tested for
integrity using vacuum, pressure, or liquid methods in accordance with requirements
developed by the manufacturer, a code of practice developed by a nationally recognized
association or independent testing laboratory, or requirements established by the
department;

HAR 11-280.l-33(a)(6)

~ Yes DNo 0N/A

S

CM
W

Within six months following the repair of any cathodically protected UST system, the
cathodic protection system was tested in accordance with section 11-280.1-31(2) and (3) to
ensure that it is operating properly; and

HAR 11-280.l-33(a)(7)

~ Yes UNo 0IM/A

8

-------
GENERAL COMMENTS

The EPA Inspection Team commenced an opening conference with Rear Admiral Tim Kott and
approximately 35 other DoD personnel on February 28, 2022. A closing conference was conducted on
March 4th.

At the time of EPA's 2022 inspection, Tanks 1 and 19 were out of service, and four additional tanks were
undergoing the clean-inspect-repair process.

The Red Hill UST system consists of two rows of 10 tanks, each with a capacity to hold 12.5 million
gallons of fuel. Navy Personnel explained that the upper portion of the tank domes are more susceptible
to corrosion because they are closertothe top of the mountain ridge, and for that reason, the tanks are
usually filled with approximately	gallons of fuel, which is below the upper dome. Each of the

Red Hill tanks can be accessed tnrougrHne Upper Tunnel and Lower Tunnel. The Upper Tunnel
contains ventilation infrastructure, fire-fighting infrastructure and access manholes for the tanks. The
Lower Tunnel contains fueling valves and three main pipelines for the three different fuel types.

REVIEW

Inspector: S. Bobby Ojha Signature: SANDEEP	Title: UST Inspector Phone: 415-972-3374

Inspector Rick SakOW Signature: RICHARD SAK0WTitle: UST Inspector Phone:415-972-3495
Review:

Supervisor: Kaoru Morimoto Signature: ^ORUMORIMOTOTitle: UST Manager Phone:415-972-3306

Page 97 of 97

-------
PHOTOGRAPH LOG

Facility

JBPHH Red Hill Bulk Fuel Storage Facility

Facility Location

Multiple locations in Aiea. Hawaii 96701

Photographer

Rick Sakow. US EPA. Region 9

Camera Equipment

Olympus Tough T-6 IPX8 Digital Camera

Inspection and Photograph Dates

The Underground Storage Tank inspection was
conducted February 28 - March 4, 2022.

Photograph 1 - File: P3010575.jpg

View of Adit Jupper Tunnel entrance.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 2 - File: P3010576.jpg

View inside Upper Tunnel entrance. The black pipe holds fire suppression liquid. The white pipe beneath

provides air ventilation.

Photograph 3 - File: P3010577.jpg

Ladder that is approximately ^^|et tall which leads to the top of a Red Hill Bulk Fuel tank. Ladder is
used to complete manual tank gauging to detennine product level.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG



(b)(3)(A)

ifef. /





1

A—tj j

lr "1 —- - 1





Photograph 4 - File: P3010578.jpg

View inside Tank 19.

(b)(3)(A)







Photograph 5 - File: P3010579.jpg

View of Automatic Fuel Handling Equipment (AFHE) monitor for Tank 20. The AFHE indicates the fuel

level is above the catwalk, which is approximately

(b)(3) (A)

above the base of the tank.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG



b) (3) (A)







Photograph 6 - File: P3010580.jpg

View of AFHE monitor for Tank 20. TheAFHE indicates the fuel level is above the catwalk, which is

approximately	above the base of the tank.

Photograph 7 - File: P3010581.jpg

View of manhole cover and maintenance door to Tank 20.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 8 - File: P3010582.jpg

View ofAFHE monitor for Tank 17. The AFHE indicates the fuel level is

was undergoing Clean Inspect and Repair (CIR) and was empty at the time the photo was taken.
NAVFAC personnel explained this was a calibration error. The sensor's lowest measurement is I

b) (3) (A)

Tank 17

(b) (3)(A

Photograph 9 - File: P3010583.jpg

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

View of Tank 18. which was actively undergoing the CIR process. NAVFAC personnel explained Tank
18 had not undergone the CIR process since 1963 or 1968. NAVFAC personnel explained Tank 18 was

drained in May 2020.

Photograph 10 - File: P3010584.jpg

View inside Tank 18. which was actively undergoing the CIR process. Facility personnel explained the

white circles identify potential deficiencies for repair.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

Photograph 12 - File: P3010586.jpg

View of the catwalk in Tank 18 facing downward.

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 11 - File: P3010585.jpg

View inside Tank 18, which was actively undergoing the CIR process. Facility personnel explained the

white circles identify potential deficiencies for repair.

Photograph 13 - File: P3010586.jpg

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

View inside Tank 18.

Photograph 14 - File: P3010588.jpg

View inside Tank 18.

Photograph 15 - File: P3010589.jpg

View inside Tank 18.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photo (Vlissing

Photograph 16 - File: P3010590.jpg

Photo missing.

Photograph 17 - File: P3010591.jpg

AFHE monitor for Tank 15 states that Tank 15 holds JP-5. The HDOH UST Permit Application stated

that Tank 15 held F-76 marine diesel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 18 - File: P3010592.jpg

AFHE for Tank 16.

Photograph 19 - File: P3010593.jpg

View of Upper Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 20 - File: P3010594.jpg

AFHE monitor for Tank 13. Tank 13 is out of service and the AFHE is not operating.

Photograph 21 - File: P3010595.jpg

View of manhole cover and maintenance door to Tank 13

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

(b)(3)(A)

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 22 - File: P3010596.jpg

AFHE monitor for Tank 11.

Photograph 23 - File: P3010597.jpg

View of manhole cover and maintenance door to Tank 11. The EPA Inspection Team observed odors of

petroleum in this area of the Upper Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 24 - File: P3010598.jpg

Duplicate view of manhole cover and maintenance door to Tank 11.

(b)(3)(A)

Photograph 25 - File: P3010599.jpg

AFHE monitor for Tank 10.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 26 - File: P3010600.jpg

View of manhole cover and maintenance door to Tank 10.

Photograph 27 - File: P3010601.jpg

View facing upward of the Tank 10 ladder that is used for complete manual tank gauging to determine

product level.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

b 3 A

Photograph 28 - File: P3010602.jpg

AFHE monitor for Tank 9.

Photograph 29 - File: P3010603.jpg

AFHE monitor for Tank 8.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 30 - File: P3010604.jpg

View of Tank 8 ladder that is used for complete manual tank gauging to determine product level.

Photograph 31 - File: P3010605.jpg

Duplicate view of Tank 8 ladder that is used for complete manual tank gauging to determine product

level.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 32 - File: P3010606.jpg

AFHE monitor for Tank 6.

Photograph 33 - File: P3010607.jpg

AFHE monitor for Tank 4.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 34 - File: P3010608.jpg

Tank 4 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole.

Photograph 35 - File: P3010609.jpg

Tank 2 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 36 - File: P3010610.jpg

Tank 2 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not obseive a gasket between the outer plate and manway hole.

Photograph 37 - File: P3010611.jpg

AFHE monitor for Tank 3.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 38 - File: P3010612.jpg

Tank 3 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole.

Photograph 39 - File: P3010613.jpg

Tank 3 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 40 - File: P3010614.jpg

AFHE monitor for Tank 2.

Photograph 41 - File: P3010615.jpg

Tank 2 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not obseive a gasket between the outer plate and inanway hole.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 42 - File: P3010616.jpg

Tank 2 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole.

Photograph 43 - File: P3010617.jpg

View of Upper Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 44 - File: P3010618.jpg

View of Upper Tunnel showing fire suppression piping.

b 3 A

Photograph 45 - File: P3010619.jpg

AFHE monitor for Tank 7.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 46 - File: P3010620.jpg

Tank 7 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole.

Photograph 47 - File: P3010621.jpg

Tank 7 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 48 - File: P3010622.jpg

Tank 7 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole.

Photograph 49 - File: P3010623.jpg

Infrastructure associated with Tank 7 with hydrocarbon staining.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3)(A)

Photograph 50 - File: P3010624.jpg

AFHE monitor for Tank 8.

Photograph 51 - File: P3010625.jpg

Tank 8 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not obseive a gasket between the outer plate and inanway hole.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3)(A)

Photograph 52 - File: P3010626.jpg

AFHE monitor for Tank 9.

Photograph 53 - File: P3010627.jpg

Tank 9 manhole cover and maintenance door. The manhole cover was fitted with washers and bolts. The
EPA Inspection Team did not obseive a gasket between the outer plate and inanway hole.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG



,«MH l»M " .

U «« CMS*. lit ;

r»*A 14. iikj

• i-itfii.i

••

Photograph 54 - File: P3010628.jpg

Tank 9 manhole cover and maintenance door. The manhole cover was fitted with washers and bolts. The
EPA Inspection Team did not observe a gasket between the outer plate and manway hole.

Photograph 55 - File: P3010629.jpg

Tank 9 manhole cover and maintenance door. The manhole cover was fitted with washers and bolts. The
EPA Inspection Team did not observe a gasket between the outer plate and manway hole.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 56 - File: P3010630.jpg

Tank 9 manhole cover and maintenance door. The manhole cover was fitted with washers and bolts. The
EPA Inspection Team did not observe a gasket between the outer plate and manway hole.

Photograph 57 - File: P3010631.jpg

Close-up view of the bolts on the maintenance door of Tank 9.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

(b)(3)(A)

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 58 - File: P3010632.jpg

AFHE monitor for Tank 10.

Photograph 59 - File: P3010633.jpg

Tank 10 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not obseive a gasket between the outer plate and manway hole.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 60 - File: P3010634.jpg

Tank 10 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole. Duct tape was
observed between the inner and outer portion of the maintenance door.

Photograph 61 - File: P3010635.jpg

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Tank 10 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole. Duct tape was
observed between the inner and outer portion of the maintenance door.

Photograph 62 - File: P3010636.jpg

Tank 10 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole. Duct tape was
observed between the inner and outer portion of the maintenance door.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

- (b) (3) (A)

Photograph 63 - File: P3010637.jpg

AFHE monitor for Tank 11.

Photograph 64 - File: P3010638.jpg

Tank 11 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not obseive a gasket between the outer plate and manway hole.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 65 - File: P3010639.jpg

AFHE monitor for Tank 12.

Photograph 66 - File: P3010640.jpg

Tank 12 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not obseive a gasket between the outer plate and manway hole.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 67 - File: P3010641.jpg

Plosejm vipw nf me bolls OP flip maintptiatirp Hnnr nf	1 2

Photograph 68 - File: P3010642.jpg

Signage for Tank 15.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 69 - File: P3010643.jpg

AFHE monitor for Tank 15.

Photograph 70 - File: P3010644.jpg

Tank 12 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not obseive a gasket between the outer plate and manway hole.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 71 - File: P3010645.jpg

Staining on wall near Tank 15.

Photograph 72 - File: P3010646.jpg

AFHE monitor for Tank 16.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 73 - File: P3010647.jpg

Tank 16 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole.

Photograph 74 - File: P3010648.jpg

Tank 16 manhole cover and maintenance door. Note that the bolts do not have washers. The EPA
Inspection Team did not observe a gasket between the outer plate and manway hole. Duct tape was
observed between the inner and outer portion of the maintenance door.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

b 3 A





Photograph 75 - File: P3010649.jpg

Piping associated with the decommissioned "tell-tale" system in the Lower Access Tunnel.

b 3 A

Photograph 76 - File: P3010650.jpg

Close-up view of the "tell-tale" system piping and a trench beneath.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 77 - File: P3010651.jpg

Close-up view of the decommissioned "tell-tale" system piping.

Photograph 78 - File: P3010652.jpg

View of a spill bucket positioned beneath the decommissioned "tell-tale" system piping,

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

PTFUELJP-5

Photograph 79 - File: P3010653.jpg

Close-up view of the decommissioned "tell-tale" system piping and a trench beneath.

Photograph 80 - File: P3010654.jpg

View of Tank 20 infrastructure.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 81 - File: P3010655.jpg

View of Tank 20 infrastructure.

Photograph 82 - File: P3010656.jpg

View of Tank 20 infrastructure. The black pipe in this photograph had pivoted leftward and dented the
adjacent ah ventilation conduit diuing the May 2021 incident.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3)(A)



Photograpli 83 - File: P3010657.jpg

View of Tank 20 infrastructure. The black pipe in this photograph had pivoted leftward during the May
6. 2021 incident and dented the adjacent ah ventilation conduit.

Photograph 84 - File: P3010658.jpg

View of Tank 20 infrastructure.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 85 - File: P3010659.jpg

View of Tank 20 infrastructure.

Photograph 86 - File: P3010660.jpg

View of Tank 20 infrastructure.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 87 - File: P3010661.jpg

View of the Aqueous Film Forming Foam (AFFF) equipment. This photograph shows where AFFF

media is mixed with water.

Photograph 88 - File: P3010662.jpg

View of trenching beneath the infrastructure seen in photograph P3010661.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 89 - File: P3010663.jpg

View of Tank 18 infrastructure.





Ml



(b)(3)(A)

Photograph 90 - File: P3010664.jpg

View of Tank 18 infrastructure.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 91 - File: P3010665.jpg

Zone 1 Sump trench in the Lower Access Tunnel.

Photograph 92 - File: P3010666.jpg

Zone 1 Sump trench in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3) (A)

/////////,
W BSGGMMM
' SS////S//1
'SSS/SS/SSJ
SSS/S/SS/St,
W'S//S/SS//SSJ

w ////////////A

"////////////„.



Wiiii • 1111 ¦ ¦ 111 ii iiiV»Vm\\V\

,//// i uir.iiwwwwwww
_	III Hi mi;

hi			

Photograph 93 - File: P3010667.jpg

Zone 1 Sump trench and infrastructure in the Lower Access Tunnel. Facility personnel explained during
the inspection that the Zone 1 Sump had filled with fuel during the May 6, 2021 release and added that
other fuel went to the Zone 7 Fuel Oil Recoveiy Sump.

Photograph 94 - File: P3010668.jpg

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Fuel Oil Reclamation pipe (white) located beneath a trench, located near the Zone 1 Sump trench in the
Lower Access Tunnel. During the inspection Facility personnel were unsure what the hole beneath the

pipe was, or where it drained to.

Photograph 95 - File: P3010669.jpg

Fuel Oil Reclamation pipe (white) located beneath a trench, located near the Zone 1 Sump trench in the
Lower Access Tunnel. During the inspection Facility personnel were unsure what the hole beneath the

pipe was, or where it drained to.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 96 - File: P3010670.jpg

Zone 7 Fuel Oil Reclamation Sump in the Lower Access Tunnel.

Photograph 97 - File: P3010671.jpg

Zone 7 Fuel Oil Reclamation Sump in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 98 - File: P3010672.jpg

Zone 7 Fuel Oil Reclamation Sump in the Lower Access Tunnel

Photograph 99 - File: P3010673.jpg

Zone 7 Fuel Oil Reclamation Sump in the Lower Access Tunnel

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 100 - File: P3010674.jpg

AFFF line. Portions of the AFFF line are metal and PVC. This image shows the metal portion.

Photograph 101 - File: P3010675.jpg

Low point on AFFF line in the Lower Access Tunnel. Portions of the AFFF line are metal and PYC. This

image shows the PVC portion.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 102 - File: P3010676.jpg

Soil vapor monitoring location in the Lower Access Tunnel.

Photograph 103 - File: P3010677.jpg

View of corroded pipe that protrudes the wall at approximately a 30-degree angle in the Lower Access
Tunnel. Facility personnel were not sure what this pipe was connected to. This pipe is located near the
soil vapor monitoring location in photograph P3010676.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 104 - File: P3010678.jpg

View of trench for the Fuel Oil Reclamation Line in the Lower Access Tunnel that discharges to Tank

311.

Photograph 105 - File: P3010679.jpg

Soil vapor monitoring location adjacent to Fuel Oil Reclamation Line and trench in the Lower Access

Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 106 - File: P3010680.jpg

Soil vapor monitoring location adjacent to Fuel Oil Reclamation Line and trench in the Lower Access

Tunnel.

Photograph 107 - File: P3010681.jpg

Tank 12 infrastructure.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

582.jpg

Open-ended pipe at Tank 12 in the Lower Access Tunnel. Facility personnel beheved this pipe was
previously used as secondary containment for a former Fuel Oil Reclamation line.

Photograph 109 - File: P3010683.jpg

View inside the pipe seen hi P3010682.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3) (A)



\ 1

MM 1

y jk

¦L3



Photograph 110 - File: P3010684.jpg

Tank 10 infrastructure.

(b)(3)(A)

Photograph 111 - File: P3010685.jpg

Open-ended pipe at Tank 10. Facility personnel believed this pipe was previously used as secondaiy
containment for a former Fuel Oil Reclamation line.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3)(A)

Photograph 112 - File: P3010686.jpg

Open-ended pipe at Tank 10. Facility personnel believed this pipe was previously used as secondaiy
containment for a former Fuel Oil Reclamation line.

Photograph 113 - File: P3010687.jpg

Frayed and exposed electrical wiring near Tank 5.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 114 - File: P3010688.jpg

Frayed and exposed electrical wiring near Tank 5

Photograph 115 - File: P3010689.jpg

Signage for Tank 6.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 116 - File: P3010690.jpg

Capped pipe at Tank 10. Facility personnel believed this pipe was previously used as secondary
containment for a former Fuel Oil Reclamation line.

f- S

'/ * 1	.. V.

^ : '

TANK

2

F -H4





. - ;

I ¦ o



Photograph 117 - File: P3010691.jpg

Signage for Tank 2.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 118 - File: P3010692.jpg

Open-ended pipe at Tank 2. Facility personnel believed this pipe was previously used as secondaiy
containment for a former Fuel Oil Reclamation line.

Photograph 119 - File: P3010693.jpg

Oily staining located near Tank 2 in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

I113

Photograph 120 - File: P3010694.jpg

Oily staining located near Tank 2 in the Lower Access Tunnel.

(b) (3)

Photograph 121 - File: P3010695.jpg

Oily staining located near Tank 2 in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 122 - File: P3010696.jpg

Oily staining beneath equipment near Tank 2 hi the Lower Access Tunnel.

Photograph 123 - File: P3010697.jpg

Oily staining beneath equipment near Tank 2 hi the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 124 - File: P3010698.jpg

Oily staining, facing upward, near Tank 2 in the Lower Access Tunnel.

Photograph 125 - File: P3010699.jpg

Overview of oily staining located near Tank 2 in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 126 - File: P3010700.jpg

Fuel Oil Reclamation Main Sump, located between Tank 1 and Tank 2 and Adit 3

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 127 - File: P3010701.jpg

Fuel Oil Reclamation Main Sump.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

i

Photograph 128 - File: P3010702.jpg

Oil-tight bulkhead isolation door in the Lower Access Tunnel.

Photograph 129 - File: P3010703.jpg

Sump adjacent to the oil-tight bulkhead isolation door seen in P3010702 in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 130 - File: P3010704.jpg

Close-up of the sump basin seen in P3010703 in the Lower Access Tunnel.

Photograph 131 - File: P3010705.jpg

Pipes that transfer Fuel Oil Reclamation (FOR) liquid to and from the Fuel Oil Reclamation Main Sump.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 132 - File: P3010706.jpg

Fuel Oil Reclamation Main Sump.

Photograph 133 - File: P3010707.jpg

Fuel Oil Reclamation Main Sump.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 134 - File: P3010708.jpg

Facility personnel explained the cart seen in this photograph was the cart that struck a low point of the
AFFF drainage line during the November 20. 2021 release.

Photograph 135 - File: P3010709.jpg

Deteriorated wrap on fuel pipeline in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

b 3 A

Photograph 136 - File: P3010710.jpg

Deteriorated wrap on fuel pipeline in the Lower Access Tunnel.

b 3 A

Photograph 137 - File: P3010711.jpg

Fuel pipeline with white marking to identify areas of pipe with gouging, corrosion, or pitting in the Lower

Access Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 138 - File: P3010712.jpg

View of a PVC portion of the AFFF line. Facility personnel explained that during the November 20,
2021 release, the low-point drain seen in this photograph was struck and released a mixture of fuel and

water.

Photograph 139 - File: P3010713.jpg

View of a PVC portion of the AFFF line. Facility personnel explained that during the November 20, 2021
release, the low-point drain seen in this photograph was struck and released a mixture of fuel and water.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 140 - File: P3010714.jpg

View of a PVC portion of the AFFF line. Facility personnel explained that during the November 20. 2021
release, the low-point drain seen in this photograph was struck and released a mixUue of fuel and water.

This poition of pipeline had high wind speeds.

(b)(3)(A)

Photograph 141 - File: P3010715.jpg

View of Lower Access Tunnel Adit 17

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 142 - File: P3020716.jpg

Hotel Pier terminal with fuel lines connected to shipping vessels.

Photograph 143 - File: P3020717.jpg

Fuel connectors and drip pan at Hotel Pier.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 144 - File: P3020718.jpg

Hotel Pier fuel pipelines entering the ground.

Photograph 145 - File: P3020719.jpg

Hotel Pier fuel pipelines entering the ground. Inspectors intentionally covered the labelmg of the fuel

lines.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG



Photograph 146 - File: P3020720.jpg
Valve Station! near

(b)(3)(AJ

(b) (3) (A

Photograph 147 - File: P30207H.jpg

Valve Stationl. neaiH^^^H.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

b)(3)(A

Photograph 148 - File: P3020722.jpg

Valve Stationl. neai fl^^^H.

Photograph 149 - File: P3020723.jpg

AFFF Retention Tank.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 150 - File: P3020724.jpg

Fuel Oil Reclamation Tank

Sf

Photograph 151 - File: P3020725.jpg

Fuel Oil Reclamation Tank

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 152 - File: P3020726.jpg

Adi H groundwater sump. Facility personnel explained that spilled fuel had discharged into this sump,
which is located approximately	from the point where fuel was released.

Photograph 153 - File: P3020727.jpg

Adi j|j groundwater sump. Facility personnel explained that spilled fuel had discharged into this sump,
which is located approximately	from the point where fuel was released.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)

(3)

'(A)





Photograph 154 - File: P3020728.jpg

French drain beneath pipeline conveying groundwater to the granular activated carbon (GAC) system

The GAC system is located outside of Adit J

1(b) (3) (A) |

*-*

Photograph 155 - File: P3020729.jpg

French drain beneath pipeline conveying groundwater to the granular activated carbon (GAC) system.

The GAC system is located outside of AdiH

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 156 - File: P3020730.jpg

View of the Red Hill Shaft, which connects to the drinking water reservoir

(b)(3)(A)

11 1

11 \|B

Photograph 157 - File: P3020731.jpg

View of the Red Hill Shaft, which connects to the drinking water reservoir.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 158 - File: P3020732.jpg

Pipes with corrosion in the Lower Access Tunnel.

b 3 A

Photograph 159 - File: P3020733.jpg

Pipes with corrosion in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

b 3 A

Photograph 160 - File: P3020734.jpg

Fuel pipeline with deterioration on pipe wrapping material in the Lower Access Tunnel.

b 3 A

Photograph 161 - File: P3020735.jpg

Fuel pipeline with deterioration ou pipe wrapping material in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 162 - File: P3020736.jpg

Fuel pipeline with deterioration on pipe wrapping material in the Lower Access Tunnel.

" "

Photograph 163 - File: P3020737.jpg

Fuel pipeline with deterioration on pipe wrapping material in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3) (A)

. -fr

' 1 ^ -v, "

MS': -A

i

I

Photograph 164 - File

Black liquid staining beneath fuel pipeln

: P3020738.jpg

lies in the Lower Access Tunnel.

b 3 A

Photograph 165 - File: P3020739.jpg

Fuel pipeline with deterioration ou pipe wrapping material in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 166 - File: P3020740.jpg

Groundwater runoff drain in floor in the Lower Access Tunnel

Photograph 167 - File: P3020741.jpg

Groundwater runoff drain in floor in the Lower Access Tunnel

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

b 3 A

Photograph 168 - Rle^>3020742.jpg

Fuel pipelines^^J and water line^J in the Lower Access Tunnel.

b 3 A

Fuel pipelines and water line|^^|in the Lower Access Tunnel, facing |^^^|the Red Hill Tank

Fami.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 170 - File: P3020744.jpg

Groundwater runoff drain in floor in the Lower Access Tunnel.

(b)(3)(A)

Photograph 171 - File: P3020745.jpg

Fuel pipeline with deterioration on pipe wrapping material and corrosion on pipe in the Lower Access

Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 172 - File: P3020746.jpg

Liquid accumulated beneath fuel pipelines in the Lower Access Tunnel

Photograph 173 - File: P3020747.jpg

Liquid accumulated beneath fuel pipelines in the Lower Access Tunnel

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 174 - File: P3020748.jpg

Liquid accumulated beneath fuel pipelines and on floor in the Lower Access Tunnel.

Photograph 175 - File: P3020749.jpg

Liquid accumulated beneath fuel pipelines and on floor in the Lower Access Tunnel

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 176 - File: P3020750.jpg

Liquid accumulated beneath fuel pipelines and on floor in the Lower Access Tunnel.

Photograph 177 - File: P3020751.jpg

Drains and liquid accumulated on floor in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 178 - File: P3020752.jpg

Salt or other crystalline deposits on the wall in the Lower Access Tunnel.

b 3 A

Photograph 179 - File: P3020753.jpg

Fuel pipelines with evidence of surface corrosion and deterioration in pipeline wrap in the Lower Access

Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3)(A)

M

Photograph 180 - File: P3020754.jpg

Fuel pipelines with surface corrosion and breaks in pipe wrapping material in the Lower Access Tunnel.

(b)(3)(A)

Photograph 181 - File: P3020755.jpg

Pipe used to convey water with corrosion present on the pipe, bolts, and piping interface in the Lower

Access Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 182 - File: P3020756.jpg

Liquid accumulated beneath fuel pipelines in the Lower Access Tunnel. Note the algae growth.

Photograph 183 - File: P3020757.jpg

Sump 5 with a ball-float.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 184 - File: P3020758.jpg

Sump 5 with a ball-float in the Lower Access Tunnel

Photograph 185 - File: P3020759.jpg

Sump 5 with a ball-float in the Lower Access Tunnel

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b) (3)

Oil-tialit bulkhead

186 - File: P3020760.jpg

isolation door and fuel pipelines in the Lower Access Tunnel

Photograph 187 - File: P3020761.jpg

Oil-tight bulkhead isolation door in the Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3)(A)



HI

Photograph 188 - File: P3020762.jpg

Fuel pipelines with evidence of corrosion and breaks in pipe wrapping material in the Lower Access

Tunnel.

(b)(3)(A)

Photograph 189 - File: P3020763.jpg

Fuel pipeline marked "*Dent / Gouge

b)(3)[A

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 190 - File: P3020764.jpg

AFFF Retention System in the Lower Access Tunnel



Photograph 191 - File: P3020765.jpg

AFFF Retention System in the Lower Access Tunnel

-------
Photograph 192 - File: P3020766.jpg

AFFF Retention System in the Lower Access Tunnel.

Photograph 193 - File: P3020767.jpg

View of Underground Piunphouse Bilge Draining Area.

Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 194 - File: P3020768.jpg

View of Underground Puinphouse Bilge Draining Area.

b 3 A

Photograph 195 - File: P3020769.jpg

View of Underground Pumphouse Bilge Draining Area.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photo Missing

Photograph 196 - File: P3020770.jpg

Photo missing.

View of Underground Pumphouse.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

b 3 A

Photograph 198 - File: P3020772.jpg

View of Underground Pumphouse Bilge Draining Area with a ventilation vent.

b 3 A

Photograph 199 - File: P3020773.jpg

Overview of Underground Pumphouse Pump Room.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 200 - File: P3020774.jpg

Fuel Oil Reclamation Sump beneath the Underground Pumphouse

Photograph 201 - File: P3020775.jpg

Fuel Oil Reclamation Sump beneath the Underground Pumphouse

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 202 - File: P3020776.jpg

Fuel Oil Reclamation Sump beneath the Underground Pumphouse

Photograph 203 - File: P3020777.jpg

Fuel Oil Reclamation Sump beneath the Underground Pumphouse

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 204 - File: P3020778.jpg

View of leaking pipe on roof.

b 3 A

View of leaking material. This pipe in this photograph is directly beneath the location seen in photograph

P3020778.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

b 3 A

Photograph 206 - File: P3020780.jpg

Dresser coupling on fuel pipeline near Tank 2.

Photograph 207 - File: P3020781.jpg

Manhole for manual tank gauging for Surge Tanks in Underground Pumphouse.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 209 - File: P3030783.jpg

Fuel Oil Reclamation Sump (Sump 7) located in the in Lower Tunnel with 5-inches of liquid in the sump.
Inspectors noted strong petroleum smells m this sump, and the tape measure used in this photograph had

fuel odors.

Photograph 208 - File: P3030782.jpg

Fuel Oil Reclamation Sump (Sump 7) located in the in Lower Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 210 - File: P3030784.jpg

Fuel Oil Reclamation Sump (Sump 7) located in the in Lower Tunnel

Photograph 211 - File: P3030785.jpg

Fuel Oil Reclamation Sump (Sump 7) located in the in Lower Tunnel

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 212 - File: P3030786.jpg

Fuel Oil Reclamation Sump (Sump 7) located in the in Lower Tunnel

Photograph 213 - File: P3030787.jpg

Fuel Oil Reclamation Sump (Sump 7) located in the in Lower Tunnel

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 214 - File: P3030788.jpg

Fuel Oil Reclamation Sump (Sump 7) located in the in Lower Tunnel

Photograph 215 - File: P3030789.jpg

Sump in Lower Access Tunnel.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 216 - File: P3030790.jpg

AFFF Sump near Zone 7 Sump.

Photograph 217 - File: P3030791.jpg

AFFF Sump near Zone 7 Sump.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 218 - File: P3030792.jpg

AFFF equipment.

Photograph 219 - File: P3030793.jpg

Tank 16 sump.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 220 - File: P3030794.jpg

Tank 16 sump.

Photograph 221 - File: P3030795.jpg

Tank 16 sump.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG



US IIS

Photograph 222 - File: P3030796.jpg
AFFF Sump.

Photograph 223 - File: P3030797.jpg
AFFF equipment.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 224 - File: P3030798.jpg

View of copper pipe used to pump out groundwater from Lower Access Tunnel

Photograph 225 - File: P3030799.jpg

Underground Pumphouse Sump.

-------
Photograph 226 - File: P3030800.jpg

Underground Pumphouse Sump.

Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 227 - File: P3030801.jpg

Underground Pumphouse Sump.

-------
Photograph 228 - File: P3030802.jpg

Underground Pumphouse Sump.

Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 229 - File: P3030803.jpg

Underground Pumphouse Sump.

-------
(b)(3)(A)

Photograph 230 - File: P3030804.jpg

Liquid stored in totes that were removed from the Underground Piunphouse Sump during the inspection.

Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Divisiou
PHOTOGRAPH LOG

Photograph 231 - File: P3030805.jpg

Liquids removed from Underground Pumphouse Sump, marked "Waste Water - Don't Drink or Use."

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 232 - File: P3030806.jpg

View of Tanks B1 and B2 at Fuel Oil Reclamation Facility.



Photograph 233 - File: P3030807.jpg

Tanks at Fuel Oil Reclamation Facility.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 234 - File: P3030808.jpg

Tanks and piping at Fuel Oil Reclamation Facility.

Photograph 235 - File: P3030809.jpg

Tanks and piping at Fuel Oil Reclamation Facility.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 236 - File: P3030810.jpg

Oil-water separators at Fuel Oil Reclamation Facility

Photograph 237 - File: P3030811.jpg

Oil-water separator at Fuel Oil Reclamation Facility

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 238 - File: P3030812.jpg

Oil-water separator at Fuel Oil Reclamation Facility

Photograph 239 - File: P3030813.jpg

Sump at Fuel Oil Reclamation Facility used to collect stormwater.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 240 - File: P3030814.jpg

Oil-water separator at Fuel Oil Reclamation Facility

Photograph 241 - File: P3030815.jpg

Oil-water separator at Fuel Oil Reclamation Facility.

-------
Photograph 242 - File: P3030816.jpg

Oil-water separator at Fuel Oil Reclamation Facility.

Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 243 - File: P3030817.jpg

Manhole cover at Fuel Oil Reclamation Facility.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 244 - File: P3030818.jpg

View inside Fuel Oil Reclamation Facility, as seen in P3030817.

Photograph 245 - File: P3030819.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 246 - File: P3030820.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817.

Photograph 247 - File: P3030821.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 248 - File: P3030822.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817.

Photograph 249 - File: P3030823.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 250 - File: P3030824.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817.

Photograph 251 - File: P3030825.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 252 - File: P3030826.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817.

m

Photograph 253 - File: P3030827.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 254 - File: P3030828.jpg

View inside Fuel Oil Reclamation Facility sump, as seen in P3030817.

Photograph 255 - File: P3030829.jpg

Rectifier 23. The reading for Rectifier 23 was VC-15. The rectifier display was broken at the time of the
inspection but was still transmitting data. Rectifier 23 is located near Makalapa Drive and North Road.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 256 - File: P3030830.jpg

Rectifier 23.

Photograph 257 - File: P3030831.jpg

Rectifier 23.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Power •
Comm •
Status *

SCOUT

SHUN"
P2S

Photograph 258 - File: P3030832.jpg

Rectifier 23 dial.

Photograph 259 - File: P3030833.jpg

Rectifier 23 labeling.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

L-

No. 10 UTF TK. 55

bJ

Photograph 260 - File: P3030834.jpg

Rectifier 23 labeling.

Photograph 261 - File: P3030835.jpg

Truck offloading dump chute near Fuel Oil Reclamation Facility.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 262 - File: P3030836.jpg

Truck offloading dump chute near Fuel Oil Reclamation Facility

)

Photograph 263 - File: P3030837.jpg

Truck offloading dump chute near Fuel Oil Reclamation Facility.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 264 - File: P3030838.jpg

Truck offloading dump chute near Fuel Oil Reclamation Facility



Photograph 265 - File: P3030839.jpg

Exterior view of truck offloading dump chute near Fuel Oil Reclamation Facility

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 266 - File: P3030840.jpg

Rectifier labeling.

Photograph 267 - File: P3030841.jpg

Rectifier equipment.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 268 - File: P3030842.jpg

Rectifier equipment.

Photograph 269 - File: P3030843.jpg

Overview of Hickam Airfield Truck Onloading Rack.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

1^1

b) (3) (A)



Photograph 270 - File: P3030844.jpg

Overview of Hickam Airfield Truck Onloading Rack.

b 3 A

Photograph 271 - File: P3030845.jpg

Oveiview of Hickam Airfield Truck Onloading Rack.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

b 3 A

Photograph 272 - File: P3030846.jpg

Receptacle at Overview of Hickam Airfield Truck Ouloadiug Rack.

Photograph 273 - File: P3030847.jpg

Drain at Hickam Airfield Truck Ouloading Rack.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 274 - File: P3030848.jpg

Rectifier interior at Hickam Airfield.

Photograph 275 - File: P3030849.jpg

Rectifier exterior at Hickam Airfield.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 276 - File: P3030850.jpg

Leaking valve in the Diamond Head Pump House, I

Photograph 277 - File: P3030851.jpg

Diamond Head Product Recovery Tank

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 278 - File: P3030852.jpg

Diamond Head Product Recovery Tank

Photograph 279 - File: P3030853.jpg

Diamond Head Product Recovery Tank

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

^ \





lUsisliiiUiiiiiiiniuWttmUvu •

iniiiiiiiiiiiiiimvi\m\\\\\\\\\\\\\\

miiiiiiiiiiimuim\um\\u\\\\\\
iiigl!l|il!lliiiiw\ \\vv\\\\\\\\\\\\\\ >

J i!! !!!SHU\\\V\\\V

JHBBmhI



Photograph 280 - File: P3030854.jpg

Ewa Product Recovery Tank

(b)(3) (A

Photograph 281 - File: P3030855.jpg

Ewa Product Recoveiy Tank with product name intentionally obscured.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 282 - File: P3030856.jpg

Ewa Product Recovery Tank Spill Bucket.

Photograph 283 - File: P3030857.jpg

Ewa Product Recovery Tank Spill Bucket Cover.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 284 - File: P3030858.jpg

Leaking valve in the Ewa Pump House.

Photograph 285 - File: P3030859.jpg

Leaking valve in the Ewa Pump House.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 286 - File: P3030860.jpg

Leaking valve in the Ewa Pump House.

Photograph 287 - File: P3030861.jpg

Leaking valve in the Ewa Pump House.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 288 - File: P3030862.jpg

Leaking valve in the Ewa Pump House.

Photograph 289 - File: P3030863.jpg

Leaking valve in the Ewa Pump House.

-------
Photograph 290 - File: P3030864jpg

Diamond Head hydrant pit^^|

Photograph 291 - File: P3030865.jpg

Diamond Head hydrant pit^H with minor amount of accumulated fluid with a odor of petroleum.

Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 292 - File: P3030866.jpg

Diamond Head hydrant pit^H with minor amount of accumulated fluid with odor of petroleum.

^Photograph 293 - File: P3030867.jpg

Diamond Head hydrant pitj^^ with minor amount of accumulated fluid with odor of petroleum.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 294 - File: P3030868.jpg

Diamond Head hydrant pit^^Bwith minor amount of accumulated fluid with odor of petroleum.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3)(A

'(b) (3) (A

Photograph 295 - File^3030869.jpg

Hydrant Pit^^|

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 296 - File: P3030870.jpg
H|Ji Hydrant Pit.

'lllllUtUH.UllttlMj

Photograph 297 - File: P3030871.jpg

gg Hydrant Pit with accumulated liquid

-------


Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 298 - File: P3030872.jpg

Hydrant Pit with accumulated liquid.

Photograph 299 - File: P3030873.jpg

Hydrant Pit with accumulated liquid.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 300 - File: P3030874.jpg
H|Ji Hydrant Pit.

Photograph 301 - File: P3030875.jpg
¦Hi Hydrant Pit.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 302 - File: P3030876.jpg
mUl Hydrant Pit.

Photograph 303 - File: P3030877.jpg

High Point Valve ||

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 304 - File: P3030878.jpg

High Point Valve J with accumulated liquid accumulated in spill bucket.

Photograpl^OS - File: P3030879.jpg

Hydrant Pit.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 306 - File: P3030880.jpg
mUl Hydrant Pit.

Hkm	r ¦

Photograph 307 - File: P3030881.jpg

|| Hydrant Pit with accumulated liquid.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 308 - File: P3040882.jpg

Overview of Fuel Oil Reclamation Facility

Photograph 309 - File: P3040883.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 310 - File: P3040884.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

Photograph 311 - File: P3040885.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 312 - File: P3040886.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.



Photograph 313 - File: P3040887.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG



Photograph 314 - File: P3040888.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

Photograph 315 - File: P3040889.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 316 - File: P3040890.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

Photograph 317 - File: P3040891.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 318 - File: P3040892.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

Photograph 319 - File: P3040893.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 320 - File: P3040894.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

Photograph 321 - File: P3040895.jpg

Duplicate photo of P3040882. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 322 - File: P3040896.jpg

Additional view of Fuel Oil Reclamation Facility.

Photograph 323 - File: P3040897.jpg

Additional view of Fuel Oil Reclamation Facility.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 324 - File: P3040898.jpg

Duplicate photo of P3040896. Duplicate caused by camera error.

Photograph 325 - File: P3040899.jpg

Duplicate photo of P3040896. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 326 - File: P3040900.jpg

Duplicate photo of P3040896. Duplicate caused by camera error.

Photograph 327 - File: P3040901.jpg

Duplicate photo of P3040896. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 328 - File: P3040902.jpg

Duplicate photo of P3040896. Duplicate caused by camera error.

Photograph 329 - File: P3040903.jpg

Additional view of Fuel Oil Reclamation Facility.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 330 - File: P3040904.jpg

Duplicate photo of P3040903. Duplicate caused by camera error.

jKs]ss^i

Photograph 331 - File: P3040905.jpg

Duplicate photo of P3040903. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 332 - File: P3040906.jpg

Duplicate photo of P3 040903. Duplicate caused by camera error.

Photograph 333 - File: P3040907.jpg

View of Tank 301 adjacent to Fuel Oil Reclamation Facility. Tank 301 is the receiving tank froml

TANK 301
9251

A

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

TANK 301
3251

Photograph 334 - File: P3040908.jpg

Duplicate photo of P3040907. Duplicate caused by camera error.

Photograph 335 - File: P3040909.jpg

Duplicate photo of P3040907. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3)(A)

TANK 301
9251



Photograph 336 - File: P3040910.jpg

Duplicate photo of P3040907. Duplicate caused by camera error.

Photograph 337 - File: P3040911.jpg

Duplicate photo of P3040907. Duplicate caused by camera error.

lANK 301
9251

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

(b)(3)(A)

TANK 301
9251

.£5 ¦	t	:5V	j,'	¦¦

Photograph 338 - File: P3040912.jpg

Duplicate photo of P3040907. Duplicate caused by camera error.

mot

RETURN TO OPERATOR
RETURN TO SERVICE

Photograph 339 - File: P3040913.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 340 - File: P3040914.jpg

View of printed records available during the inspection.

Photograph 341 - File: P3040915.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 342 - File: P3040916.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 344 - File: P3040918.jpg

View of printed records available during the inspection.

Photograph 345 - File: P3040919.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 346 - File: P3040920.jpg

View of printed records available during the inspection.

Photograph 347 - File: P3040921.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

RH 05

RTS & Monitor
Log

TANK
5

%

Photograph 348 - File: P3040922.jpg

View of printed records available during the inspection.

Photograph 349 - File: P3040923.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 350 - File: P3040924.jpg

View of printed records available during the inspection.

Photograph 351 - File: P3040925.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 352 - File: P3040926.jpg

View of printed records available during the inspection.

Photograph 353 - File: P3040927.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Jm

r

Photograph 354 - File: P3040928.jpg

View of printed records available during the inspection.

Photograph 355 - File: P3040929.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

UPPER TANK
FARM BERM
WATER DRAIN
LOG

UPPER TANK
FARM BERM
WATER DRAIN
LOG

FUEL DEPARTMENT

navsup flcjbpHh

FUEL DEPARTMENT
NAVSUP FLC JBPHH

Photograph 356 - File: P3040930.jpg

Duplicate photo of P3 040929. Duplicate caused by camera error.

UPPER TANK
FARM BERM
WATER DRAIN
LOG

fuel department
NAVSUP FLCJBPHH

UPPER TANK
FARM BERM
WATER DRAIN
LOG

FUEL DEPARTMENT
NAVSUP FLCJBPHH

Photograph 357 - File: P3040931.jpg

Duplicate photo of P3040929. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

UPPER TANK
FARM BERM
WATER DRAIN
LOG

UPPER TANK
FARM BERM
WATER DRAIN
LOG

fuel department

NAVSUPFLCJBPHH

FUEL DEPARTMENT
NAVSUP H.CJBPHH

Photograph 358 - File: P3040932.jpg

Duplicate photo of P3 040929. Duplicate caused by camera error.

Photograph 359 - File: P3040933.jpg

Duplicate photo of P3040929. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

UPPER TANK
FARM berm
WATER DRAIN
LOG

UPPER TANK
FARM BERM
WATER DRAIN
LOG

FUEL DEPARTMENT
NAVSUP FIX JBPHH

FUEL DEPARTMENT
NAVSUP FLC JBPHH

Photograph 360 - File: P3040934.jpg

Duplicate photo of P3 040929. Duplicate caused by camera error.

Photograph 361 - File: P3040935.jpg

Duplicate photo of P3040929. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 362 - File: P3040936.jpg

Duplicate photo of P3 040929. Duplicate caused by camera error.

UPPER TANK

farm berm

WATER DRAIN
LOG

UPPER TANK
FARM BERM
WATER DRAIN
LOG

fuel DEPARTMENT

navsup flcjbphh

FUEL DEPARTMENT
NAVSUP FLCJBPHH

Photograph 363 - File: P3040937.jpg

Duplicate photo of P3040929. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 364 - File: P3040938.jpg

View of printed records available during the inspection.

Photograph 365 - File: P3040939.jpg

Duplicate photo of P3040939. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 366 - File: P3040940.jpg

Duplicate photo of P3040939. Duplicate caused by camera error.

Photograph 367 - File: P3040941.jpg

Duplicate photo of P3040939. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 368 - File: P3040942.jpg

Duplicate photo of P3040939. Duplicate caused by camera error.

Photograph 369 - File: P3040943.jpg

Duplicate photo of P3040939. Duplicate caused by camera error.

-------
Photograph 370 - File: P3040944.jpg

Duplicate photo of P3040939. Duplicate caused by camera error.

Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 371 - File: P3040945.jpg

Duplicate photo of P3040939. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 372 - File: P3040946.jpg

View of printed records available during the inspection.

*

>1

	

Photograph 373 - File: P3040947.jpg

Duplicate photo of P3040946. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 374 - File: P3040948.jpg

Duplicate photo of P3040946. Duplicate caused by camera error.

Photograph 375 - File: P3040949.jpg

Duplicate photo of P3040946. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 376 - File: P3040950.jpg

Duplicate photo of P3040946. Duplicate caused by camera error.

Photograph 377 - File: P3040951.jpg

Duplicate photo of P3040946. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 378 - File: P3040952.jpg

Duplicate photo of P3040946. Duplicate caused by camera error.

Photograph 379 - File: P3040953.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

I

Photograph 380 - File: P3040954.jpg

Duplicate photo of P3040953. Duplicate caused by camera error.

2020
SPCC
PERIODIC
INSPECTIONS

Photograph 381 - File: P3040955.jpg

Duplicate photo of P3040953. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 382 - File: P3040956.jpg

Duplicate photo of P3040953. Duplicate caused by camera error.

Photograph 383 - File: P3040957.jpg

Duplicate photo of P3040953. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 384 - File: P3040958.jpg

Duplicate photo of P3040953. Duplicate caused by camera error.

Photograph 385 - File: P3040959.jpg

Duplicate photo of P3040953. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 386 - File: P3040960.jpg

View of printed records available during the inspection.

Photograph 387 - File: P3040961.jpg

Duplicate photo of P3040960. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 388 - File: P3040962.jpg

Duplicate photo of P3040960. Duplicate caused by camera error.

Photograph 389 - File: P3040963.jpg

Duplicate photo of P3040960. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 390 - File: P3040964.jpg

Duplicate photo of P3040960. Duplicate caused by camera error.

Photograph 391 - File: P3040965.jpg

Duplicate photo of P3040960. Duplicate caused by camera error.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 392 - File: P3040966.jpg

Duplicate photo of P3040960. Duplicate caused by camera error.

Photograph 393 - File: P3040967.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 394 - File: P3040968.jpg

View of printed records available during the inspection.

Photograph 395 - File: P3040969.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 396 - File: P3040970.jpg

View of printed records available during the inspection.

Photograph 397 - File: P3040971.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 398 - File: P3040972.jpg

View of printed records available during the inspection.

Photograph 399 - File: P3040973.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 400 - File: P3040974.jpg

View of printed records available during the inspection.

Photograph 401 - File: P3040975.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 402 - File: P3040976.jpg

View of printed records available during the inspection.

Photograph 403 - File: P3040977.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 404 - File: P3040978.jpg

View of printed records available during the inspection.

Photograph 405 - File: P3040979.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 406 - File: P3040980.jpg

View of printed records available during the inspection.

Photograph 407 - File: P3040981.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 408 - File: P3040982.jpg

View of printed records available during the inspection

Photograph 409 - File: P3040983.jpg

View of printed records available during the inspection

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 410 - File: P3040984.jpg

View of printed records available during the inspection.

Photograph 411 - File: P3040985.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 412 - File: P3040986.jpg

View of printed records available during the inspection.

Photograph 413 - File: P3040987.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 414 - File: P3040988.jpg

View of printed records available during the inspection.

Photograph 415 - File: P3040989.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 416 - File: P3040990.jpg

View of printed records available during the inspection.

Photograph 417 - File: P3040991.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 418 - File: P3040992.jpg

View of printed records available during the inspection.

Photograph 419 - File: P3040993.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 420 - File: P3040994.jpg

View of printed records available during the inspection.

Photograph 421 - File: P3040995.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 422 - File: P3040996.jpg

View of printed records available during the inspection.

Photograph 423 - File: P3040997.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 424 - File: P3040998.jpg

View of printed records available during the inspection.

Photograph 425 - File: P3040999.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 426 - File: P3041G00.jpg

View of printed records available during the inspection.

1. Truck Loading Rack

Photograph 427 - File: P3041001.jpg

View of printed records available during the inspection.

Binder #2
UST

-	DOH Records Location Letter

-	Third Party Performance Claims

-	Temporary Closure Records

Binder
UST
Permit
Application

HICKAM

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 428 - File: P3041Q02.jpg

View of printed records available during the inspection.

Photograph 429 - File: P3041003.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4. 2022.
Facility: JBPHH Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 430 - File: P3041004.jpg

View of printed records available during the inspection.

Photograph 431 - File: P3041005.jpg

View of printed records available during the inspection.

-------
Inspection Date: February 28 -March 4, 2022.
Facility: JBPF1H Red Hill Bulk Fuel Storage Facility

R9 Enforcement and Compliance Assurance Division
PHOTOGRAPH LOG

Photograph 432 - File: P3041G06.jpg

View of printed records available during the inspection.

Photograph 433 - File: P3041Q07.jpg

View of printed records available during the inspection.

-------
Year

1948

1980

2014

1949

1971

1975

1981

1972

1970

1982

1983

1963

1941

1942

1943

1944

1945

1946

1947

1950

1951

1952

1953

1954

1955

1956

1957

1958

1959

1960

1961

1962

1964

1965

1966

1967

1968

1969

1973

1974

1976

1977

1978

1979

1984

1985

Volume Released
35,700
32,476
31,140
23,428
21,861
10,671
8,373
4,810
4,623
3,318
2,229
1

0.0076
0.0075
0.0074
0.0073
0.0072
0.0071
0.0070
0.0069
0.0068
0.0067
0.0066
0.0065
0.0064
0.0063
0.0062
0.0061
0.0060
0.0059
0.0058
0.0057
0.0056
0.0055
0.0054
0.0053
0.0052
0.0051
0.0050
0.0049
0.0048
0.0047
0.0046
0.0045
0.0044
0.0043

M

T

1/T

1

139.5

0.007

2

50.1

0.020

3

30.5

0.033

4

21.9

0.046

5

17.1

0.058

6

14.1

0.071

7

11.9

0.084

8

10.3

0.097

9

9.1

0.110

10

8.2

0.122

11

7.4

0.135

12

6.8

0.148

13

6.2

0.161

14

5.8

0.174

15

5.4

0.186

16

5.0

0.199

17

4.7

0.212

18

4.4

0.225

19

4.2

0.238

20

4.0

0.250

21

3.8

0.263

22

3.6

0.276

23

3.5

0.289

24

3.3

0.302

25

3.2

0.314

26

3.1

0.327

27

2.9

0.340

28

2.8

0.353

29

2.7

0.366

30

2.6

0.378

31

2.6

0.391

32

2.5

0.404

33

2.4

0.417

34

2.3

0.430

35

2.3

0.442

36

2.2

0.455

37

2.1

0.468

38

2.1

0.481

39

2.0

0.494

40

2.0

0.506

41

1.9

0.519

42

1.9

0.532

43

1.8

0.545

44

1.8

0.558

45

1.8

0.570

46

1.7

0.583

-------
1986

1987

1988

1989

1990

1991

1992

1993

1994

1995

1996

1997

1998

1999

2000

2001

2002

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

2013

2015

2016

2017

2018

2019

0.0042

47

1.7

0.596

0.0041

48

1.6

0.609

0.0040

49

1.6

0.622

0.0039

50

1.6

0.634

0.0038

51

1.5

0.647

0.0037

52

1.5

0.660

0.0036

53

1.5

0.673

0.0035

54

1.5

0.686

0.0034

55

1.4

0.698

0.0033

56

1.4

0.711

0.0032

57

1.4

0.724

0.0031

58

1.4

0.737

0.0030

59

1.3

0.750

0.0029

60

1.3

0.762

0.0028

61

1.3

0.775

0.0027

62

1.3

0.788

0.0026

63

1.2

0.801

0.0025

64

1.2

0.814

0.0024

65

1.2

0.826

0.0023

66

1.2

0.839

0.0022

67

1.2

0.852

0.0021

68

1.2

0.865

0.0020

69

1.1

0.878

0.0019

70

1.1

0.890

0.0018

71

1.1

0.903

0.0017

72

1.1

0.916

0.0016

73

1.1

0.929

0.0015

74

1.1

0.942

0.0014

75

1.0

0.954

0.0013

76

1.0

0.967

0.0012

77

1.0

0.980

0.0011

78

1.0

0.993

0.0010

79

1.0

1.006

-------
Year

Volume Released

1941



1942



1943



1944



1945



1946



1947



1948

35,700

1949

23,428

1950



1951



1952



1953



1954



1955



1956



1957



1958



1959



1960



1961



1962



1963

1

1964



1965



1966



1967



1968



1969



1970

4,623

1971

21,861

1972

4,810

1973



1974



1975

10,671

1976



1977



1978



1979



1980

32,476

1981

8,373

1982

3,318

1983

2,229

1984



1985



1986



1987



1989



1990



1991



1992



1993



1994



1995



1996



1997



1998



1999



2000



2001



2002



2003



2004



2005



2006



2007



2008



2009



2010



2011



2012



2013



2014

27,000

2015



2016



2017



2018



2019



Total

174,490

Volume Released

-------
2000

2001

2002

2003

2004

2005

2006

2007

2008

2009

4,623
21,861
4,810

-------
1/11/2014
1/9/2014
1/8/2014
1/7/2014
1/6/2014
1/4/2014
1/2/2014
12/31/2013
12/27/2013
12/24/2013
12/23/2013
12/20/2013
12/13/2013

Stop Date	Tank

1/13/2014	5

1/11/2014	5

1/9/2014	5

1/8/2014	5

1/7/2014	5

1/6/2014	5

1/4/2014	5

1/2/2014	5

12/29/2013	5

12/25/2013	5

12/24/2013	5

12/22/2013	5

12/20/2013	5
1/25/1983

Ending

Starting level level in
in tank (feet) tank (feet)

Days (gpd) (gallons) (gallons) (gallons)

Jropped
Jropped
Jropped
Jropped
Jropped
Jropped
Jropped
Jropped
Jropped
Jropped
Jropped
Jropped
Jropped

/el drops during leak test

drop is approximately 4896 gal Ions
59" drop IS approximately 441gallons
53" drop is approxiamtely 4504gallon:
58" drop is approximately 392gallons
19" drop IS approximately 5826gallon:
12" drop IS approximately 588gallons
59" drop is approximately 441gallons
59" drop is approximately 4847gallon:
52" drop is approximately 98 gal Ions
15" drop IS approximately 5630gallon:
54" drop IS approximately 196gallons
56" drop is approximately 294 gal Ions
5" drop is approximately 2938 gal Ions

evel drops during leak test
evel drops during leak test
ate is approximately lgpd
oss rate approximately 10gpd

2/10/1981
5/23/1980
2/3/1981
1/30/1981
1/29/1981
11/13/1980
10/22/1980

11/12/1980

2/11/1981
2/5/1981
2/5/1981
2/10/1981
1/30/1981

*ank refilled

After repair project, leak rates ranged from 4.5 to 17.9gpd with n
Gaugeshowsleakratetobeapprox 1440 gpd





5/1/1975 5/7/1975

3/1/1972 4/26/1972

Unexplained drop in fuel

8/21/1970 10/23/1970

Unexplained drop in fuel

3/27/1963 4/15/1963

Telltale #8 started leaking

20ccper4hours(or5mlperhour)isapproximately 0.0317gpd

12/10/1949 12/14/1949
12/1/1948 2/9/1949
12/1/1948 2/9/1949

Added fuel and lost 3-5/8" in 4 days

Losses ceased after 3/1/49

Losses ceased after 3/1/49	

3/1/2008 3/1/2008

12/1/2000 12/1/2000

Following earthquake on June 28, 1948

5-6 gal Ions drainedbackintoTankl9whiledrillinggastesthole
lgallon of fuel spilled
Consolidation of previous reports
Suspected release
Contaiminated soil found during co
Contaiminated soil found during co
Tank level rises during leak test
Tank level rises during leak test
Tank removed from service for leak repairs

1 850 bbl is approximately 35,700 gal Ions

Suspect DFM/SFO which was last stored in Tank 16 on 10DEC1971

10/2/1981 10/3/1981

5/20/1978 5/22/1978
12/26/1977 4/19/1978
1/20/1975 2/10/1978
10/12/1977 12/26/1977
5/21/1976

4/23/1976
1/8/1975

5/20/1976

4/20/1976

12/23/1975
5/23/1973
2/10/1972
11/14/1973 11/26/1973
3/1/1973 3/31/1973

One leak found at 188' level
Tank refilled and leaking badly
Tank was refilled and showed leakage
Reported leak

Tank leaking badly after return to service
Drainage from telltales#3 and #9
Significant telltale leakage overweekend
Drainage from telltales#3 and #8
Telltale #8 started leaking
Unexplained drop in fuel level

2/18/1966 9/27/1967
3/21/1965 9/21/1965

Reported leak
Telltale #1 leaking

Leak on 10' sample tap
Telltale leaking 1 drop i
Telltale leak found leaking 2 quarts per day
Telltale #1 collector ring leaking. Sump alarm sounded.
Tank emptied for suspected leak with no
Found and repaired leak in collector ring
Telltale #6 leaking at rate of lgallon every 90 seconds
Fuel and water draining from telltales

No leak found.

5/6/1965
8/19/1964
8/17/1964

2/24/1964 2/24/1964

Drainage from telltales
Drainage from telltales
Drainage from telltales
Drainage from telltales

; atlquartevery2.5minutes

1/1/1964
4/21/1963

1/30/1964
5/20/1963

4/15/1963 4/21/1963
3/27/1963 4/4/1963

8/14/1953 8/20/1953

Tank appearsto be leaking at 85'

Reported known leak
Telltale #8 leaking while tank is empty
Telltale #8 leaking while tank is empty
Telltale #8 leaking while tank is being emptied
Telltale #2 leaking
Repaired leak on drain line
Approximately 1500 gal Ions leak from telltale
Suspected leak

Completed weld repair.

3 dpm is approximately 0.05gpd

lgallon every 90 seconds is approxiamtely 960gpd
lgallon every 1.25 hours equates to 19.2gpd

1/16/1947 1/19/1947

Start draining w/out nipplt
1 quart per hour

ldropperlOsecondsandlquartevery4minutes,
Draining at 1 quart every 2.5 minutes

1 0.5ccper4hoursisapproximately 0.0007925gpd
1 lccper6hoursisapproximately 0.00105gpd
1 3.4ccper4hoursisapproximately 0.005389gpd
1 2ccper4hoursisapproximately 0.00317gpd

lgallon every 13 minutes is approximately 110gallons per day

Draining at 5 gal I o ns per 8 minutes per notes

Draining at 5 gal I o ns per 8 minutes per notes

-------
Notes

1.	Table generated from Tank History compiled in March and April of 1999 from all available sources by J. Gammons FISC Fuel SUPT.

2.	Data from AFHE Pearl Harbor Tank 0105 Findings dated 06 FEB 2014.

3.	Data from JAN 2008 Red Hill Bulk Fuel Storage Facility Groundwater Protection Plan.

4.	Information from memo to Office of Legislative Affairs

5.	Information from Technical Study of Possibility of Contamination of Basal Water Sources from RHBFSF.

6.	Reduction in level in Tank #16 was assumed to be past leakage. Fuel analysis indicates the fuel detected was not currently stored in the tank and had not been stored since early 1980s.

7.	Leak rate could not be determined.

8.	Identified from Tank # Unverified History.

9.	Identified in Whitacre emails from 2014.

-------
Tank

MILCON P-0060 Start Date

MILCON P-0060 Completion Date

Comments

1

5/15/1978

9/28/1982

Telltales removed. Tank leaked following restoration.

2

12/28/1981

4/1/1983

Tank continued to undergo leak testing as of 4-1-83. Contractor will return NLT September 1983 for final rework.

3

3/5/1982

12/1/1982



4

9/1/1981

4/1/1983

Tank continued to undergo leak testing as of 4-1-83. Contractor will return NLT September 1983 for final rework.

5

5/10/1981

4/1/1983

Tank continued to undergo leak testing as of 4-1-83. Contractor will return NLT September 1983 for final rework.

6

3/23/1981

3/16/1983

Tank formally accepted by NSC Pearl in letter to ROICC Pearl.

7

4/9/1981

5/3/1981

Tank accepted.

8

4/17/1981

4/1/1983

Tank continued to undergo leak testing as of 4-1-83. Contractor will return NLT September 1983 for final rework.

9

7/25/1978

2/5/1981



10

10/25/1978

4/1/1983

Extensive leak testing completed during filling operations. Tank continued to undergo leak testing as of 4-1-83. Contractor will return NLT September 1983 for final rework.

11

7/10/1978

1/9/1981

Extensive leak testing completed during filling operations.

12

2/27/1980

5/5/1981

Tank was removed for leak repairs.

13

5/30/1980

2/12/1982



14

4/17/1980

2/11/1982

Tank removed from service again on 2/11/82 to complete leak repairs.

15

8/1/1980

7/19/1981

Tank later removed from service for leak repairs on 8/30/81 and subsequently refilled for leak testing on 1/6/82.

16

2/1/1981

12/28/1981

Tank returned to service for leak testing following completion of leak repairs.

-------














Leak

Release

Telltale

Unknown











Starting level

Ending level

No.

Rate

Volume

Release

Release



Start Date

Stop Date

Tank

Description

in tank (feet)

in tank (feet)

Days

(gpd)

(gallons)

(gallons)

(gallons)

Calculation Notes

1/11/2014

1/13/2014

5

Level dropped

223.50

223.42

2

2,448

4,896

-

4,896

1" drop is approximately 4896
gallons

1/9/2014

1/11/2014

5

Level dropped

223.51

223.50

2

221

441

-

441

0.09" drop is approximately 441
gallons

1/8/2014

1/9/2014

5

Level dropped

223.59

223.51

1

4,553

4,553

-

4,553

0.93" drop is approxiamtely 4504
gallons

1/7/2014

1/8/2014

5

Level dropped

223.59

223.59

1

392

392

-

392

0.08" drop is approximately 392
gallons

1/6/2014

1/7/2014

5

Level dropped

223.69

223.59

1

5,826

5,826

-

5,826

1.19" drop is approximately 5826
gallons

1/4/2014

1/6/2014

5

Level dropped

212.42

212.41

2

294

588

-

588

0.12" drop is approximately 588
gallons

1/2/2014

1/4/2014

5

Level dropped

212.43

212.42

2

221

441

-

441

0.09" drop is approximately 441
gallons

12/31/2013

1/2/2014

5

Level dropped

212.51

212.43

2

2,424

4,847

-

4,847

0.99" drop is approximately 4847
gallons

12/27/2013

12/29/2013

5

Level dropped

196.93

196.93

2

49

98

-

98

0.02" drop is approximately 98
gallons

12/24/2013

12/25/2013

5

Level dropped

171.28

171.18

1

5,630

5,630

-

5,630

1.15" drop is approximately 5630
gallons

12/23/2013

12/24/2013

5

Level dropped

164.59

164.59

1

196

196

-

196

0.04" drop is approximately 196
gallons

12/20/2013

12/22/2013

5

Level dropped

152.59

152.59

2

147

294

-

294

0.06" drop is approximately 294
gallons

12/13/2013

12/20/2013

5

Level dropped

106.31

106.26

7

420

2,938

-

2,938

0.6" drop is approximately 2938
gallons

3/15/1983

4/22/1983

1

Tank level rises during leak test

230.17

230.23

38

(26)

(1,004)

-

(1,004)



2/20/1983

3/15/1983

1

Tank level rises during leak test

230.11

230.17

23

(47)

(1,090)

-

(1,090)



11/8/1982

1/25/1983

1

Tank level drops during leak test

229.85

229.73

76

30

2,229

-

2,229



8/3/1982

9/28/1982

1

Tank level drops during leak test

200.99

200.97

55

16

871

-

871



7/28/1982

8/3/1982

1

Tank level drops during leak test

229.99

229.85

6

403

2,417

-

2,417



2/11/1982

2/12/1982

14

Tank removed from service for leak
repairs





1

-

-

-

-



1/14/1982

2/3/1982

16

Loss rate is approximately 1 gpd





20

1

20

-

20



1/13/1982

1/14/1982

16

Loss rate approximately 10 gpd

242.00



1

10

10

-

10



1/8/1982

2/12/1982

13

Tank leaks above 188' level

188.00



35

-

-

-

-



11/12/1981

12/23/1981

16

One laek found at 188' level

188.00



41

-

-

-

-



10/23/1981

11/10/1981

16

Tank refilled and leaking badly

242.00



18

-

-

-

-



10/2/1981

10/3/1981

15

Tank was refilled and showed leakage

185.00



1

-

-

-

-



9/1/1981

9/2/1981

12

Reported leak





1

-

-

-

-



7/14/1981

7/19/1981

15

Tank leaking badly after return to
service





5

-

-

-

-



-------












Leak

Release

Telltale

Unknown











Starting level

Ending level

No.

Rate

Volume

Release

Release



Start Date

Stop Date

Tank

Description

in tank (feet)

in tank (feet)

Days

(gpd)

(gallons)

(gallons)

(gallons)

Calculation Notes

2/10/1981

2/11/1981

12

Tank refilled

100.00



1

1,400

1,400

-

1,400

Assumed non-telltale leakage

1/30/1981

2/10/1981

10



239.00



11

15

165

-

165

Assumed non-telltale leakage

5/23/1980

2/5/1981

9

After repair project, leak rates ranged
from 4.5 to 17.9 gpd with no action
noted





258

6

1,528



1,528



2/3/1981

2/5/1981

12

Gauge shows leak rate to be approx
1440 gpd

100.00



2

1,440

2,880

-

2,880

Assumed non-telltale leakage

1/29/1981

1/30/1981

10



240.00



1

693

693

-

693

Assumed non-telltale leakage

1/9/1981

1/10/1981

10



242.10



1

1,206

1,206

-

1,206

Assumed non-telltale leakage

11/12/1980

1/9/1981

10



235.00



58

5

273

-

273

Assumed non-telltale leakage

11/13/1980

1/8/1981

7



206.90



56

3

174

-

174

Assumed non-telltale leakage

10/22/1980

11/12/1980

7



206.90



21

3

55

-

55

Assumed non-telltale leakage

10/4/1980

11/12/1980

10



235.00



39

2

94

-

94

Assumed non-telltale leakage

9/10/1980

10/4/1980

7



207.00



24

12

288

-

288

Assumed non-telltale leakage

9/10/1980

10/4/1980

10



235.00



24

13

307

-

307

Assumed non-telltale leakage

9/12/1980

9/15/1980

11



25.00



3

165

495

-

495

Assumed non-telltale leakage

9/8/1980

9/11/1980

11



44.20



3

377

1,131

-

1,131

Assumed non-telltale leakage

8/9/1980

9/10/1980

7



207.00



32

13

406

-

406

Assumed non-telltale leakage

8/26/1980

9/8/1980

11



51.00



13

487

6,331

-

6,331

Assumed non-telltale leakage

8/23/1980

8/25/1980

11



100.00



2

785

1,570

-

1,570

Assumed non-telltale leakage

7/22/1980

8/21/1980

10



235.00



30

13

399

-

399

Assumed non-telltale leakage

8/18/1980

8/21/1980

11



149.00



3

1,070

3,210

-

3,210

Assumed non-telltale leakage

8/16/1980

8/18/1980

11



182.00



2

1,380

2,760

-

2,760

Assumed non-telltale leakage

8/13/1980

8/15/1980

11



202.00



2

1,614

3,228

-

3,228

Assumed non-telltale leakage

8/12/1980

8/13/1980

11



214.00



1

2,412

2,412

-

2,412

Assumed non-telltale leakage

8/8/1980

8/11/1980

11



235.00



3

1,497

4,491

-

4,491

Assumed non-telltale leakage

8/1/1980

8/7/1980

7



209.90



6

208

1,248

-

1,248

Assumed non-telltale leakage

7/26/1980

7/31/1980

7



214.80



5

334

1,670

-

1,670

Assumed non-telltale leakage

7/21/1980

7/25/1980

7



235.00



4

609

2,436

-

2,436

Assumed non-telltale leakage

4/19/1978

8/24/1978

1

Drainage from telltales #3 and #9

183.55



127

104

13,221

13,221

-



5/20/1978

5/22/1978

7

Significant telltale leakage over
weekend





2

-

-

-

-



12/26/1977

4/19/1978

1

Drainage from telltales #3 and #8

184.27



114

69

7,874

7,874

-



1/20/1975

2/10/1978

17

Telltale #8 started leaking

237.00



1,117

-

-

-

-



10/12/1977

12/26/1977

1

Unexplained drop in fuel level

184.29

184.27

75

13

999

999

-



5/20/1976

5/21/1976

13

Leak in tank with no additional details





1











5/1/1976

5/2/1976

12

Reported leak





1

-

-

-

-



4/20/1976

4/23/1976

10

Telltale #1 leaking





3

1

3

3

-

60 drops per minute is
approximately 1 gpd

1/1/1976

1/1/1976

5

Leak in sample line





-

-

-

-

-

Assumed 1st day of year since no
date was recorded

12/23/1975

1/3/1976

5

Leak on 10' sample tap





-

-

-

-

-



-------
Start Date

Stop Date

Tank

Description

Starting level
in tank (feet)

Ending level
in tank (feet)

No.
Days

Leak
Rate
(gpd)

Release
Volume
(gallons)

Telltale
Release
(gallons)

Unknown
Release
(gallons)

Calculation Notes

5/1/1975

5/7/1975

1

Unexplained drop in fuel level

189.99

189.81

6

1,778

10,671

-

10,671



5/23/1973

1/8/1975

16

Telltale leaking 1 drop in 20 seconds





595

0

30

30

-

3 dpm is approximately 0.05 gpd

2/10/1972

8/8/1974

5

Telltale leak found leaking 2 quarts per
day





910

1

455

455

-



11/14/1973

11/26/1973

7

Telltale #1 collector ring leaking. Sump
alarm sounded.





12

-

-

-

-



3/1/1973

3/31/1973

12

Tank emptied for suspected leak with
no other additional details. No leak
found.

20.00

15.00

30











12/11/1972

12/12/1972

13

Found and repaired leak in collector ring





1

-

-

-

-



3/1/1972

4/26/1972

1

Unexplained drop in fuel level

230.77

230.04

56

86

4,810

-

4,810



7/27/1971

9/2/1971

1

Unexplained drop in fuel level

230.69

230.39

37

136

5,031

-

5,031



10/24/1970

5/3/1971

1

Unexplained drop in fuel level

230.08

229.16

191

88

16,830

-

16,830



8/21/1970

10/23/1970

1

Unexplained drop in fuel level

230.44

230.17

63

73

4,623

-

4,623



6/25/1969

7/10/1969

17

Telltale #6 leaking at rate of 1 gallon
every 90 seconds





15

960

14,400

14,400

-

1 gallon every 90 seconds is
approxiamtely 960 gpd

2/18/1966

9/27/1967

1

Fuel and water draining from telltales

154.90



586

0

-

-

-



3/21/1965

9/21/1965

5

Leak in telltale #2





184

19

3,533

3,533

-

1 gallon every 1.25 hours equates
to 19.2 gpd

5/3/1965

5/6/1965

1

Drainage from telltales

198.91



3

0

1

1

-

27 cc

8/18/1964

8/19/1964

1

Drainage from telltales

49.98



1

-

-

-

-

Start draining w/out nipple, slow
and trace amount

8/10/1964

8/17/1964

1

Drainage from telltales

49.98



7

6

42

42

-

1 quart per hour

8/4/1964

8/9/1964

1

Drainage from telltales

154.00



5

87

433

433



1 drop per 10 seconds and 1
quart every 4 minutes, 10
seconds

8/1/1964

8/3/1964

1

Leak from telltale at 1 quart every 2.5
minutes

215.40



2

144

288

288

-

Draining at 1 quart every 2.5
minutes

6/9/1964

6/9/1964

19

Discovered leak around weld in tank
bottom. Completed weld repair.

0.00



-

-

-

-

-



2/24/1964

2/24/1964

6

Tank appears to be leaking at 85' level

85.00



-

-

-

-

-



1/1/1964

1/30/1964

12

Reported known leak in dome section
with no other info furnished





29

-

-

-

-



5/7/1963

5/20/1963

19

Telltale #8 leaking while tank is empty

0.00



13

0

0

-

0

0.5 cc per 4 hours is
approximately 0.0007925 gpd

4/21/1963

5/7/1963

19

Telltale #8 leaking while tank is empty

0.00



16

0

0

-

0

1 cc per 6 hours is approximately
0.00105 gpd

4/15/1963

4/21/1963

19

Telltale #8 leaking while tank is being
emptied





6

0

0

-

0

3.4 cc per 4 hours is
approximately 0.005389 gpd

-------














Leak

Release

Telltale

Unknown











Starting level

Ending level

No.

Rate

Volume

Release

Release



Start Date

Stop Date

Tank

Description

in tank (feet)

in tank (feet)

Days

(gpd)

(gallons)

(gallons)

(gallons)

Calculation Notes

3/27/1963

4/15/1963

19

Telltale #8 started leaking





19

0

1



1

20 cc per 4 hours (or 5 ml per
hour) is approximately 0.0317
gpd

3/27/1963

4/4/1963

19

Telltale #2 leaking





8

0

0

-

0

2 cc per 4 hours is approximately
0.00317 gpd

10/24/1959

10/24/1959

4

Repaired leak on drain line





1

0

0

-

0



4/28/1958

5/12/1958

9

Approximately 1500 gallons leak from
telltale





14

110

1,500

1,500



1 gallon every 13 minutes is
approximately 110 gallons per
day

1/1/1973

1/2/1973

10

Suspected leak





1

-

-

-

-



8/21/1953

9/15/1953

1

Leak found in telltale #7





25

-

-

-

-



8/14/1953

8/20/1953

1

Product draining from telltale

219.11



6

900

5,400

5,400

-

Draining at 5 gallons per 8
minutes per notes

7/5/1953

7/5/1953

3

Repaired leak on collector ring





1

-

-

-

-



12/10/1949

12/14/1949

16

Added fuel and lost 3-5/8" in 4 days

242.15



4

4,437

17,748

-

17,748

3.625" in 4 days

7/24/1949

8/30/1949

16

Added fuel and lost 2.25" from telltale
in 11 days

167.63



11

1,001

11,011

11,011

-

2.25" lost in 11 days

12/1/1948

2/9/1949

3

Losses ceased after 3/1/49





70

60

4,260

-

4,260



12/1/1948

2/9/1949

17

Losses ceased after 3/1/49





70

20

1,420

-

1,420



7/21/1948

7/27/1948

16

Leak

242.44



6

1,001

6,009

6,009

-

Assumed 1001 gpd (2.25" in 11
days)

6/28/1948

7/21/1948

16

Following earthquake on June 28, 1948





23

1,552

35,700

-

35,700

850 bbl is approximately 35,700
gallons

10/28/1947

10/29/1947

2

Leak in telltale #9

231.23



1

-

-

-

-



1/16/1947

1/19/1947

1

Leak in telltale

50.00



3

900

2,700

2,700

-

Draining at 5 gallons per 8
minutes per notes

Total















244,433

67,897

176,536



-------
4/7/22, 1:05 PM

About Red Hill

0. Find Your Region or Installation

About Red Hill

When Pearl Harbor was attacked on Dec. 7, 1941, enemy planes failed to destroy vital American fuel reserves, a failure that would
have consequences in the early months of World War II. The U.S. Navy was aware of the vulnerability of above-the-ground fuel
tanks, so construction was already underway for a one-of-a-kind fuel facility deep within the basalt rock of nearby Red Hill. Today,
the Red Hill Bulk Fuel Facility can operate without external power, is physically protected and cyber-hardened and is critical
infrastructure for the nation's defense. The 20 tanks within Red Hill, are steel-lined concrete up to four feet thick, including a layer of
gunite, and can store millions of gallons of jet or marine fuel used by the U.S. Air Force, Army, Marines, Navy, Coast Guard and
Hawaii National Guard. In January 2014, Tank 5 experienced a release of 27,000 gallons of fuel due to a contractor's error and an
ineffective response and oversight. After that one-time extreme release, the Navy and Defense Logistics Agency intensified
modernization of the facility and monitoring of groundwater and drinking water. The Navy continues to work with Environmental
Protection Agency and Hawaii Department of Health regulators under an Administrative Order on Consent to improve the facility
and protect the environment. Since 2006, DOD has invested $260 million in Red Hill, and modernization continues in oversight,
technology, operating procedures and the means to protect our shared drinking water. Red Hill continues to be a national strategic
asset that provides power for sea control, maritime security, regional stability, humanitarian assistance and continued prosperity in
the Indo-Asia-Pacific region.

History

Before the United States entered World War II, the Roosevelt Administration became concerned about the vulnerability of the many
above-ground fuel storage tanks at Pearl Harbor. In 1940 it decided to build a new underground facility that would store more fuel
and be safe from an enemy aerial attack.

Construction

The Red Hill site would provide unprecedented flow rates of fuel due to its elevation. In addition, the site's unique geological
characteristics, including basalt rock, could support such large tanks. Federal, local government and contracted engineers and
geologists performed many surveys of the Koolau Range and eventually reached a consensus on Red Hill as the best choice because
it is mostly regular basalt.

Their original plan was to build four large underground tanks. These would be horizontal, as all underground tanks were at the time.
However, during the planning process, the engineers decided to build the tanks vertically because construction and excavation
could occur simultaneously. This was possible because a vertical shaft drilled through the centerline of the tank would allow
excavated rock to funnel down onto a series of conveyor belts in the lower access tunnel.

Planners and engineers began the process by acquiring the real estate, staging equipment and materials, and building a work camp.
The 3,900 workers worked around the clock, seven days a week, to complete the project. Construction started by excavating the
vertical shafts for all 20 tanks concurrently with mining of the upper access and lower access tunnels. The tunnels were aligned
directly in the middle of the parallel rows of shafts. Once perpendicular to the shafts, cross tunnels were mined to connect the shafts
to the main access tunnels.

For constructability and safety reasons (cave-ins), the upper domes needed to be built first, so the miners excavated individual ring
tunnels around the circumference of each of the future upper dome bases. They then scoped out the area of the domes and
proceeded to construct the steel framing, steel liner and rebar. Workers continuously poured concrete that ranged in thickness from
two feet at the crown to eight feet at the base. Once the concrete cured, it was pre-stressed by pressure grouting the area between
the concrete and the basalt.

Red Hill construction. 1941

Upon completion of the excavation, workers erected a steel tower in the center to the full height of 250 feet. The tower served to
support concrete chutes, pipes, booms, and other equipment necessary to install the piping, concrete, and steel linings. Workers
then began to erect the steel liner and rebar incrementally so that they could pour concrete in stages. Concrete was poured
continually and workers had to remove wooden shoring as concrete filled. They injected pressurized grout to pre-stress the
concrete by filling void space between the concrete and the gunite. When finished, the tanks were tested by slowly filling them with
water while laborers in boats physically checked the entire surface area of the steel liner.

The Japanese attack on Pearl Harbor took place during the construction of Red Hill. As a result, a portion of the site was used to
bury a large number of the fatalities. Those not claimed by families were moved to the National Memorial Cemetery of the Pacific
when it opened after the war.

The Department of Defense has spent more than $200 million on continual technological modernization and environmental testing
at Red Hill since 2006. The facility monitors the fuel level in each tank to one sixteenth of an inch and controls the movement of fuel
throughout the facility. If a tank level decreases by as little as half an inch, alarms will sound in Red Hill's control room, which is
continuously staffed.

Share This Page

https://www.cnic.navy.mil/regions/cnrh/om/red-hill-tank/about-red-hill.html

1/2

-------
4/7/22, 1:05 PM

About Red Hill

aamn

COTCr.

• TlCCT * flOHlCR ¦ F/iMlLV JL



USAJOBS

Site Links

EEO
FOIA

Navy

Hvperlink Notice

USA.gov

CCS



Webmaster Email
Naw Recruiting
Contact Us
Inspector General
No Fear Act Data
Accessi bilitv/
Section 508

Address



Stay Connected

Commander, Navy Region Hawaii

850 Ticonderoga St

Pearl Harbor, HI 96860-5101



BlSoHa

This is an Official US Navy Website

https://www.cnic.navy.mil/regions/cnrh/om/red-hill-tank/about-red-hill.html

2/2

-------
DEPARTMENT OF THE NAVY
NAVAL SUPPLY SYSTEMS COMMAND
5450 CARLISLE PIKE
MECHANIC8BURG, PA 17050

5830

Ser SUP00/078
14 Oct 21

FINAL ENDORSEMENT on

Itr 5830 of 15 Sep 21

From: Commander, Naval Supply Systems Command

To: Commanding Officer, NAVSUP Fleet Logistics Center Pearl Harbor

Subj: COMMAND INVESTIGATION INTO THE FUEL SPILL AT THE RED HILL BULK
FUEL STORAGE FACILITY ON OR ABOUT 6 MAY 2021

1.	Reviewed and approved.

2.	1 am forwarding this investigation to you for review, corrective action and any administrative
and/or disciplinary action(s) that you may deem appropriate. I direct that fuel personnel at Red
Hill shall review the established procedures and conduct training where needed. Additionally, I
direct you to collaborate with Navy Petroleum Office, Naval Facilities Engineering and
Expeditionary Warfare Center, Defense Logistics Agency Energy and Defense Logistics Agency
J6 to address contributing factors to the 6 May event, as described in paragraph 5 of the enclosed
investigation. Report back directly to me when these actions are complete.

3.	My point of contact concerning this matter, and specifically for anyone requesting a copy of

nercial:

Copy to:
File

-------
5830
15 Sep 21

From: Deputy Officer in Charge, NAVSUP Naval Petroleum Office
To: Commander, NAVSUP

Subj: AMENDMENT TO COMMAND INVESTIGATION INTO THE FUEL SPILL AT THE
RED HILL BULK FUEL STORAGE FACILITY ON OR ABOUT 6 MAY 2021

Ref: (a) Investigation appointing order and modifications

(b)	Report of Command Investigation into the Fuel Spill at the Red Hill Bulk Fuel Storage
Facility on or about 6 May 2021, dated 25 Jun 21

(c)	Report of Root Cause Analysis of the JP-5 Pipeline Damage, dated 7 Sep 21

1.	In accordance with reference (a), reference (b) is amended as follows to incorporate review of
reference (c) and consolidate conclusions based on engineering analysis provided in that document.

2.	Reference (c) supports the investigator's initial impression that a dynamic transient surge
damaged the JP-5 pipeline system in Red Hill on 6 May. Engineering analysis and modeling explains
that the root cause of the incident was the Control Room Operator's (CRO) failure to follow the
valve opening and closing sequence delineated in FLCPH's Specific Operations Orders. Due to this
failure, fuel passed by a pair of closed butterfly valves in the Underground Pumphouse, allowing a
vacuum to form within the JP-5 pipeline. When the skin valve for Red Hill Tank 12 (RH12) was
subsequently opened, the inrush of fuel from the tank into the pipeline collapsed the vacuum and
created a dynamic transient surge.

3.	Reference (c) explains that multiple contributing factors existed:

(a)	Use of butterfly valves,	as isolation valves was a contributing factor.
For several minutes, in violation of Specific Operations Orders for the evolution, these two butterfly
valves were the only closed valves between RH12 and Surge Tank^^^J). During that time, under
the weight of the contents of thc[0fi^U9] JP-5 line, these valves allowed fuel to leak past them.

This allowed formation of a vacuum that later collapsed, resulting in the rapid compression of air and
creation of a dynamic transient surge.

(b)	The set point of the out-of-balance alarm in AFHE was a contributing factor. An out-of-
balance alarm in AFHE warns the CRO that the amount of fuel moving into the destination tank is
not equal to the amount moved out of the source tank. On 6 May, the out-of-balance alarm was set at
|j|i|j|S|gallons (gal) for both Evolutions 3 and 4. AFHE recordings of fuel tank inventories show that
966 gal flowed into the destination tank, STK|, during Evolution 3 without a corresponding decrease
in RH12, the source tank, or Red Hill Tank 20 (RH20). In Evolution 4, another 672 gal moved from
the JP-5 pipeline into STK| without a corresponding decrease in a Red Hill tank. This total of 1,638
gal of fuel that moved out of the JP-5 pipeline into STI<| was below the out-of-balance alarm set
point. However, that fuel movement was significant because it contributed to forming the vacuum
whose later collapse resulted in a dynamic transient surge.

(c)	The lack of an AFHE indication of a pressure drop was a contributing factor. The low-
pressure alarm for the pressure indicator transmitter (PIT) in the vicinity of the two butterfly valves
was set to alarm at -9 psig. When pressure in the pipeline dropped rapidly from 125 down to 31 psig,

-------
AFHE did not sound an alarm to notify the CRO, although the drop in pressure was another indicator
of a problem.

(d) The use of expansion couplings in sections of piping affected by maintenance projects
was the final contributing factor. At the time of the event, multiple pipeline and fuel tank
maintenance projects were underway, and the JP-5 piping system included temporary modifications
to accommodate those projects. Modifications included expansion couplings in cross-tunnel pipeline
sections nearest Tanks	¦ No arrangements had been made to restrain the pipeline

motion on either side of the expansion couplings during maintenance. Unified Facilities Code, UFC
3-460-01, Design: Petroleum Fuel Facilities 9-3.3 recommends that permanent pipes be arranged so
that they have in-line restrained sliding pipe supports or other method of maintaining alignment 011
each slide of the expansion joint. Because the expansion couplings in Red Hill were not restrained,
they were free to move in multiple dimensions when the surge hit, thus exacerbating the resulting
damage.

4.

I

F

5.

(b) (5)

-------
5830
25 Juii 21

From:	Deputy Officer 111 Charge, NAVSUP Naval Petroleum Office

To: Commander, Naval Supply Systems Command (NAVSUP)

Subj: COMMAND INVESTIGATION INTO THE FUEL SPILL AT THE RED HILL BULK
FUEL STORAGE FACILITY ON OR ABOUT 6 MAY 2021

Ref: (a) .TAGINST 5800.7G

End: (1)

(2)

(3)

(4)

(5)

(6)

(V)

(8)

(9)

(10)

(11)

(12)

(13)

(14)

(15)

(16)

(17)

(18)

(b) (6)
(b) (6)
(b) (6)
(b) (6)

(b) (6)
(b) (6)

Appointing order and modifications

| interview summary dated 11 Jiui 2021
interview summary dated 10 Jim 2021

interview summary dated 10 Jim 2021
interview summary dated 10 Jun 2021
Operation, Maintenance, Environmental, and Safety Plan for Defense Fuel Support
Point Pearl Harbor Bulk Terminal

interview summary dated 10 Jun 2021
interview summary dated 14 Jim 2021
AFHE event and alarm logs for 6 May 2021

6 May 2021 specific operations order for transferring JP-5 from Red Hill Tank 12 to
Tank 20

6 May 2021 specific operations order for transferring JP-5 from Red Hill Tank 12 to
Tank 9

Investigator observations and analysis

interview summary dated 14 Jim 2021
interview summary dated 14 Jun 2021
interview summary dated 11 Jim 2021

interview summary dated 11 Jiui 2021
interview summary dated 9 Jim 2021
Red Hill Fuel Release Management Inquiry

(b) (6)
(b) (6)
(b) (6)
(b) (6)
(b) (6)



PRELIMINARY STATEMENT

1.	As directed by enclosure (1) and conducted in accordance with reference (a), this is a
command investigation into the facts and circumstances surrounding the fuel spill that occurred
on or about 6 May 2021 at the Red Hill Bulk Fuel Storage Facility.

2.	The focus of this investigation is on determining the cause of the 6 May fuel spill, how much
was released, and the impact of the release on the environment.

3.	Reference (a) was reviewed and enclosures (2) through (18) are submitted to support the
finding of facts, opinions, and recommendations reported in this investigation.

-------
4.	All reasonably available evidence required for this investigation was collected and each
objective of the appointing order has been met except validating NAVFAC EXWC efforts, since
those efforts are still ongoing. When their final report, including root cause analysis, is made
available, this report may be updated to reflect their results.

5.	My investigation did not reveal a directly attributable cause for the fuel release that occurred
on or about 6 May at the Red Hill Bulk Fuel Storage Facility. Additional engineering analysis is
needed.

FINDINGS OF FACT

1. At 0800 on 6 May 2021,	assumed Day Shift watch as Control Room

Operator (CRO) in NAVSUP FLC Peart HatijorFuelJDepartment,	assumed

duties as Red Hill Rover (RHR) withas RHR under instruction, and |gaj|
assumed duties as Kuahua Rover (KR), responsible for visually checking valves,
piping, and other facilities in the Underground Pumphouse (UGPH) and the above ground
portions of the fuel terminal. [Encls. (2)-(6)]

(b) (6)	IBM)

(bmrnmmw (6)

2. At 1600^

likewise relieved
[Encls. (7) and (8)]

as CRO for the Swing Shift. |||j|

took over as KR.

3. At 1800.	noted in fuels control system, AFHE, that Evolution 3 was finished.

;	l^ffliad started Involution 3 during the previous watch; it included transferring JP-5

from Red Hill Tank 12 (RH12) to Surge Tank^Hfi^GjS] and then pumping that JP-5 back up to
Red Hill Tank 20 (RH20), [Encl. (9)]

4. In the same minute,	marked Evolution 4 as started in AFHE; this evolution

involved transferring JP-5 from RH12 toHNjlj| and then pumping that JP-5 up to Red Hill Tank
9 (RH9). [Encl. (9)]

5. The Specific Operations Order for Evolution 3 directed that the CRO close all valves and
return the piping system to its normal configuration once the transfer was complete. Uf|j|

closed some but not all of the JP-5 pipeline valves specified before starting me second
evolution. [Encls. (9) through (11)]

6. On or about 1817,Hm^Wm heard an explosion from his watch station in Red Hill's lower
tunnel. He stepped out of the room and observed fuel spilling into the tunnel from the RH20
area. He called the CRO. [Encl. (8)]

7. The CRO verified that RH20 valves were closed and the fuel level in RH20 was not changing.
He determined that the spill was from the JP-5 pipeline and not a fuel tank, so he closed valves
for RH12 which was in use at the time and began to slack the JP-5 pipeline by allowing it to
chain into STKHadjacent to UGPH. [Encls. (7) and (9)]

-------
8. The CRO initiated notifications to his chain of command. [Encl. (7)]

9.	As part of the fuel spill response that ensued, a water wash-down of the lower Red Hill tunnel
was conducted to flush fuel into the floor drains that led to sumps where the fuel collected for
transfer to Fuel Oil Reclaimed (FOR) Tank Hi. Some amount of fuel-water mixture entered the
soil vapor monitoring vaults at RH20 and Red Hill Tank 18 (RH18). [Encl. (12)]

10.	The estimated amount of JP-5 released in the lower Red Hill tunnel on 6 May is 1,618
gallons. 1,580 gallons were recovered, for a difference of approximately 38 gallons. [Encl (12)]

11.	Air samples pulled from soil vapor monitoring wells near Red Hill Tank 17, RH18, and
RH20 after 6 May showed elevated readings for total volatile organic compounds (VOC). [Encl
(12)]

12.	No increase in fuel has been detected in the Red Hill groundwater monitoring wells since the
6 May event. This includes the nearest groundwater monitoring well in the vicinity of Red Hill
Tanks 18 and 20. [Encl (12)]

OPINIONS

1. No malicious intent is suspected.

2. NAVSUP FLC Pearl Harbor Fuel Department's training program, recordkeeping, Specific
Operations Orders, and Operations Manual are adequate.

3. It is unlikely that either throttle valve used in the transfer evolution,
allowed significant fuel flow past them while they were closed.

(b) (3) (A)

4. Even if[|flIBIC8^B did allow significant flow of fuel past them while closed, it is
unlikely that the 55 seconds it took for ball valve flffiffljjto close and stop all flow was fast
enough to cause a dynamic hydraulic surge (hammer) capable of reflecting up the hill and
blowing off the expansion couplings at RH18 and RH20.

5.	Additional engineering analysis beyond the capability of the investigator is needed to
determine the root cause of the 6 May pipeline event.

6.	None of the small amount of JP-5 that entered the soil vapor monitoring vaults at Red Hill
Tanks 18 or 20 has migrated downward to the basal aquifer approximately 100 feet below the
bottom of the tanks.

Recommendations

1. Revisit this investigation report upon promulgation of NAVFAC EXWC's root cause analysis
of the 6 May pipeline event.

-------
7/2/2021

-------
HNA/FAC

Naval Facilities Engineering Systems Command

Naval Facilities Engineering Systems Command Hawaii

Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01
JBPHH, O'ahu, Hawai'i

January 2022

-------
This page intentionally left blank

-------
HNA/FAC

Naval Facilities Engineering Systems Command

Naval Facilities Engineering Systems Command Hawaii

Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01
JBPHH, O'ahu, Hawai'i

January 2022

Prepared for NAVFAC Hawaii by

AECOM Technical Services Inc
1001 Bishop Street Suite 1600
Honolulu HI 96813-3698

N62742-17-D-1800
CTO N6274222F0106

-------
This page intentionally left blank

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Table of Contents

Table of Contents	iii

Acronyms and Abbreviations	v

1.0 Introduction and Purpose	1

2.0 Background	1

3.0 Regulatory Framework	7

3.1	HEER Office Technical Guidance Manual	7

3.2	Site Specific Conceptual Site Model for LNAPL	7

3.3	Evaluation of Environmental Hazards at Sites with Contaminated Soil and
Groundwater (Volume 2)	8

4.0 Phased Site Characterization Plan	10

4.1	In-Tunnel Characterization	10

4.1.1	Geophysical Characterization of Shallow and Deep Subsurface Features	10

4.1.2	Additional Surface SVMP Installation and Sampling	19

4.1.3	Near-Surface Intrusive Assessment	24

4.1.4	Shallow, Intermediate, and Deep Subsurface SVMPs	25

4.2	External Characterization	30

4.2.1 OWDF Leach Field Subsurface Characterization	30

5.0 Sample Details	36

5.1	Sample Custody Requirements	36

5.1.1	CoC Sample Identification Number	36

5.1.2	Descriptive Identification Number	36

5.1.3	Handling, Shipping, and Custody	38

5.2	Laboratory QC Samples	38

6.0 References	38

Appendices

A Project Schedule

B Analytical Data Package Requirements for Chemical Analyses
C Standard Operating Procedures

Figures

1	In-Tunnel Site Features Map 	3

2	Exterior Site Features Map	5

3	Example 2D GPR Profile for a Lithology Mapping Survey Along a River Channel
Using a 100-MHz Antenna (m = meters)	11

4	Example Combined 3D Grid of Data from Individual 2D Profiles	12

5	GPR pulseEKKO PRO System, with 50-MHz Antennae Frequency	13

6	Electrical Resistivity Imaging from a Fuel Tanker Spill	15

7	Supersting R8 Multichannel Resistivity System, Survey Equipment, and Features	16

in

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

8	Electrical Resistivity Acquisition Inside a Tunnel	17

9	Geophysical Survey Design	20

10	General Layout of Characterization Activities in the Tunnel	21

11	Schematic of Single and Nested SVMPs	26

12	Illustration of Connection between SVMP and Summa Canister	28

13	Exterior Subsurface Soil Boring (Direct-Push) Sampling Layout	33

Tables

3-1 Target Analytes for Middle-Distillate Contaminated Media	9

3-2 DOH Environmental Action Levels	9

5-1 Area Identifiers	37

5-2 Sample Type and Matrix Identifiers	37

5-3 Field QC Sample Type Identifiers	38

iv

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Acronyms and Abbreviations

C	degrees Celsius

|ig/L	micrograms per liter

2D	two-dimensional

3D	three-dimensional

bgs	below ground surface

BTEX	benzene, toluene, ethylbenzene, and xylenes

CoC	chain of custody

CTO	contract task order

DOH	Hawai'i Department of Health

DQO	data quality objective

DU	decision unit

EAL	Environmental Action Level

ER	electrical resistivity

ft	foot/feet

GPR	ground-penetrating radar

HEER	Hazard Evaluation and Emergency Response

Hg	mercury

I	current

ID	identification

IP	induced polarization

JBPHH	Joint Base Pearl Harbor-Hickam

JP-5	Jet Fuel Propellant 5

LCSM	conceptual site model for light nonaqueous-phase liquid

LEL	lower explosive limit

LIF	laser-induced fluorescence

LNAPL	light nonaqueous-phase liquid

MHz	megahertz

MTP	membrane-interface probe

MIS	multi-increment sampling

mg/kg	milligrams per kilogram

mL	milliliter

msl	mean sea level

NAVFAC	Naval Facilities Engineering Systems Command

NSZD	natural source-zone depletion

OWDF	Oily Waste Disposal Facility

PAH	polynuclear aromatic hydrocarbon

PID	photoionization detector

ppmv	parts per million by volume

PVC	polyvinyl chloride

QC	quality control

v

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

QSM	Quality Systems Manual

RCRA	Resource Conservation and Recovery Act

SOP	standard operating procedure

SVMP	soil vapor monitoring point

TBD	to be determined

TGM	Technical Guidance Manual

TPH	total petroleum hydrocarbons

TPH-d	total petroleum hydrocarbons - diesel range organics

TPH-g	total petroleum hydrocarbons - gasoline range organics

TPH-o	total petroleum hydrocarbons - residual range organics (i.e., TPH-oil)

U.S.	United States

V	voltage

VAC	volts alternating current

VOA	volatile organic analyte

VOC	volatile organic compound

vi

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

1.0 Introduction and Purpose

This Site Characterization Plan is provided to document the scope of work proposed to characterize
the nature and extent of petroleum hydrocarbon that is impacting U.S. Navy Well 2254-01 (also
known as Red Hill Shaft).

Areas of concern that will be characterized in this investigation are:

•	Areas underground within the Facility tunnels, Figure 1, including:

-	The U.S. Navy Well 2254-01 water development tunnel

-	The U.S. Navy Well 2254-01 pump station

-	The impacted areas of the Adit 3 tunnel

-	The impacted areas of the Pearl Harbor tunnel (Adit 1 tunnel)

•	Areas external to the underground workings, Figure 2, including:

-	The sump drain underground holding tank

-	The sump drain underground leach tank

-	The associated leach field

This Characterization Plan is prepared under Contract N62742-17-D-1800, Contract Task Order
(CTO) N6274222F0106.

The purpose of this Site Characterization Plan is to develop logistics, operating procedures, and
methodologies to conduct a comprehensive phased investigation of immediate soil/rock vapor,
soil, and rock that is and may in the future be impacted by light nonaqueous-phase liquid (LNAPL)
from the November 20, 2021 release of JP-5 that occurred in the Adit 3 tunnel in proximity to the
U.S. Navy Well 2254-01 water development tunnel and pump station.

This plan includes the following appendices:

•	Appendix A - Project Schedule

•	Appendix B - Analytical Data Package Requirements for Chemical Analyses

•	Appendix C - Standard Operating Procedures

2.0 Background

On November 20, 2021, a release of JP-5 jet fuel occurred in the Adit 3 tunnel of the Red Hill
Bulk Fuel Storage Facility (Facility). Approximately 19,000 gallons of JP-5 was released from an
overhead 14-inch PVC pipe at a location approximately 400 feet (ft) east of the Adit 3 Pump
Station and approximately 200 ft east of the upper Pearl Harbor tunnel. The location of the release
point was in close proximity to the underlying U.S. Navy Well 2254-01 water development tunnel
that extends greater than 1,200 ft northeast of the pump station at an elevation of approximately

1

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

0-20 ft above mean sea level (msl) (see Figure 1). Subsequently, Navy divers entered the water
development tunnel and swam approximately 300 ft east of the pump station; they reported
observing fuel dripping into the water tunnel. Skimmers and floating absorbent booms are
currently being used to remove the LNAPL fuel from the surface of the water development tunnel
and to prevent it from floating into the production well chamber.

Fuel ran along the tunnel floor, westward likely in the low point between the centrally located rail
lines, past the Pearl Harbor tunnel and the Pump Station, which also directly overlay the water
development tunnel. Fuel was disposed of in a sump, approximately 750 ft west of the release
point.

Fuel that was disposed of in the sump likely migrated into the environment directly at this point,
and also likely was distributed along the Hume pipe drainage system that runs between the rails in
Adit 3 throughout the study area:

Fuel likely traveled eastward and westward in the subfloor Hume drain:

•	Eastward, fuel was observed in the US Navy Well 2254-01 water development tunnel,
following the observance of fuel odors and impacts to residents that were served by the
well later in the week of November 21, 2021.

•	Westward, fuel had the potential to migrate within the sump drainage system via a sump
pump to approximately 150 ft from the entrance of Adit 3, and another 225 ft under the
Adit 3 loading area to reach the sump drain holding tank and connected sump drain leach
tank located at the northwest perimeter of the Facility, adjacent to South Halawa Stream.

Upon the first indications that there was a fuel-like odor in drinking water in homes served by the
Red Hill source, the U.S. Navy Well 2254-01 was turned off on November 28, 2021.

Between December 15 and 17, 2021, 47 subslab soil vapor monitoring points (SVMPs) were
installed into petroleum-impacted segments of the Adit 3 and Pearl Harbor tunnels. Results from
hand-held organic vapor detectors (photoionization detectors [PIDs]) that sampled these SVMPs
between December 17 and 24, 2021 indicated elevated petroleum vapors under the concrete tunnel
floors. Organic vapor maxima, or hotspots, were noted directly over the water development tunnel
in the vicinity of the release area, and at just below the merge of the Adit 3 tunnel and the Pearl
Harbor tunnel. Organic vapors were also elevated throughout the lower portion of the Adit 3
tunnel, highest surrounding the sump.

2

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Date

iU«-m Alb-tHS



Al-100



Al>250



A34HH



A1-*IH



JU*kK



Al-KO



¦klj-Ktt AJb-HC

M-ro

AliOSS Alb-*JSD

A34TC

A2-KM

aj-jk

fUa-lM

>Ub-l»

M-17S

Ala-314

Alb-2M

A1-1K

A2-2H'



UiHt Alfc-ioa

AMIS.

Alft-XU

Alb-lift

AJ-17S

AMU

12/17/2021

120 92



67



101



55



43



39



40



24

33

22

24 35

36

44

29

B3

95

69

56

51



27

36

56

51

47

36

47

2B3



12/20/202 J

350 269



235



17B



as



96



67



B5



65

73

57

54 69

NT

65

32

92

3 OS

42

57

69

7

33

5B

43

75

142

275

246

290

15

12/21/2021

NT NT



NT



m



NT



NT



NT



NT



NT

iNT

NT

NT NT

NT

NT

NT

NIT

NT

NT

71

73

15

66

6B

66 76

72

76

$7

1B1

17

12/22/2021

115 114



55



10fi



51



62



62



37



45

6D

42

56 45



92



69 £5

36

36

45

7

30

50

23

35

49

41

49

96

IB

12/23/2021

405 40B



IDE



350



192



233



205



13B



235

203

151

25B 101

9.3

302

9

257

321

112

73

157

4

102

121

35

120

163

22B

196

407

24

12/241/2021

2D1 244



120



281



2B2



131



462



101



443

471

IDS

423 208

NT

437

NT

475

490

71

116

374

NT

37

40 B

197

73

139

403

155

45B

17

0^\

J 5-IK

a^}»

is*m

2S+S50

1S+12S

2SOK"

34^075

2S-CM

21*025

12/17/2021

33

20

40

79

69

49

39

3D

59

12/20/2023

37

39

B2

54

83

473

323

135

110

1.2,' 21,' 202 2

42

40

68

43.

86

139

233

36

54

12/22/2023

25

23

35

S5

38

S3

31

65

39

23 :. i:

B2

S7

133

132

142

241

252

192

205

•a/MfMH

39

76

127

133

57

260

577

269

42

Figure It In-Tunnel Site Features Map

3

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

This page intentionally left blank

4

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

LeabhiT ank«

'tjpldjni

Sump Drain Pipe (EstimatelHSasUiron)

Adit 3

OWDFMW03A

Legend

Channelized Halawa Stream
Holding Tank
Sump Drain Pipe
Leach Tank
Monitoring Well

Figure 2: Exterior Site Features Map

5

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

This page intentionally left blank

6

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

3.0	Regulatory Framework

This site characterization will be conducted in accordance with the Resource Conservation and
Recovery Act (RCRA), which is regulated by the Hawai'i Department of Health (DOH), Hazard
Evaluation and Emergency Response (HEER) Office.

3.1	HEER Office Technical Guidance Manual

The HEER Office Technical Guidance Manual (TGM) for the Implementation of the Hawaii State
Contingency Plan.is a living document that is updated periodically (DOH 2021). This Site
Characterization Plan was developed in consultation with DOH and utilizes guidance from the
TGM to prepare sample collection strategies. General strategies include the use of discrete for soil:

• The HEER Office strongly encourages the use of Multi Increment/Decision Unit [DU]
strategies to investigate contaminated soil when appropriate such as developing risk.
However, MIS sampling is not appropriate for delineating contamination.

Discrete samples collected at biased sample point locations based on professional judgment will
be used to develop a conservative estimate for JP-5 during this initial phase of the characterization,
for delineation purposes such as screening sites for the presence of large spill areas to identify the
extent and to help select DU boundaries for collection of more detailed MIS samples, if necessary.

3.2	Site Specific Conceptual Site Model for LNAPL

In 2017, the DOH HEER Office published a LNAPL/Petroleum Guide (DOH 2018), which
provides a tiered guidance on developing a Conceptual Site Model for Light Nonaqueous-Phase
Liquid (LCSM). This guidance is the basis for tasks presented in this Plan. The objectives of this
Plan include:

1.	A phased approach to data collection, where early data collection phases inform later
phases.

2.	Develop a Site-specific Conceptual Site Model for LNAPL including soil, soil vapor,
unsaturated fractured rock, and groundwater.

3.	Data collection technology that will allow temporal changes in media conditions, including
soil vapor, temperature, geophysical attributes, etc.

4.	Identify migration pathways, including drain corridors, pipelines, and stratigraphic
preferential pathways to receptors and vulnerable resources.

5.	Expedite interim removal actions to mitigate immediate unacceptable threats.

7

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

3.3 Evaluation of Environmental Hazards at Sites with Contaminated Soil and
Groundwater (Volume 2)

DOH's technical perspective and regulatory guidance on the characterization of petroleum-
impacted soil and groundwater are described in Section 6 (Soil, Soil Vapor and Groundwater
Action Levels for TPH) of this guidance (DOH 2017) as follows:

•	Petroleum is a complex mixture that degrades into potentially toxic metabolites.

•	Non-specific, aliphatic and aromatic compounds and related degradation compounds make
up the overwhelming majority of the mass collectively referred to as Total Petroleum
Hydrocarbons or TPH" (refer to Volume 1, Section 2.6.1).

•	Risk to human health and the environmental posed by petroleum releases is evaluated in
terms of both TPH and individual, "indicator" compounds such as benzene, toluene,
ethylbenzene and xylenes (BTEX) as well as naphthalene, 1-methylnaphthalene, and 2-
methylnaphthalene and other targeted polyaromatic hydrocarbons (PAHs). The latter only
make up a small percentage of the total mass in fuels and in vapors but can pose a
significant risk due to their higher toxicity.

Appendix A, Section 4.1.6 (LNAPL Plume Delineation) of the referenced guidance (DOH 2017)
identifies soil borings as parts of the LNAPL characterization process, including the following
delineation methods for soil:

•	If the depth of the source of a release is known, then the approximate upper extent of that
release can be inferred.

•	Head space measurements for volatile organics will typically show an increase in
concentration within the LNAPL zones. Plotting these on a simple chart of depth against
concentration will typically show the inferred bulk LNAPL zone (mobile or residual).

•	Visual and olfactory comments are typically logged as well, giving another indication of
the presence of LNAPL.

•	Soil samples are often collected and analyzed chemically, which will give another set of
clear LNAPL indications. In general, TPH analytic results (for the appropriate fuel carbon
range) greater than 250 mg/kg are indicative of residual LNAPL (because soil has a limited
sorbance capacity).

Target petroleum-related analytes identified in the above guidance are listed in Table 3-1, and
relevant DOH Environmental Action Levels (EALs) are listed in Table 3.2.

8

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Table 3-1: Target Analytes for Middle-Distillate Contaminated Media

Petroleum Product

Media

Recommended Target Analytes

Middle Distillates:
diesel, kerosene, Stoddard
solvents, heating fuels, jet fuels,
etc..

Soil

TPH, BTEX, naphthalene, and
methylnaphthalenes (1- and 2-)

Soil Vapor

TPH, BTEX, naphthalene, and methane

Groundwater

TPH, BTEX, naphthalene, and
methylnaphthalenes (1- and 2-)

Source: (DOH 2017 Vol. 2, Table 6-1)

Table 3-2: DOH Environmental Action Levels

Medium

Analytical
Method

Analyte

Soil EALs
(mg/kg)a

Groundwater
EALS
(jig/L)h

Soil Vapor
EALs
(jig/m3)c

Soil (mg/kg)

SW 8260

TPH-g

100/450/700

500/220/940

4.9 xlO6





Benzene

500/1.2/0.3

500/300

6,300





Toluene

500/820/0.78

170/5

1.8 xlO7





Ethylbenzene

480/62/0.9

40/1,000

2 xlO5





Xylenes

260/130/1.4

30/70

3.5 xlO5



SW 8270

Naphthalene

500/28/3.1

20/10,000

1.1 xlO4





1 -Methylnaphthalene

500/170/0.89

21/17

9.8 xlO5





2-Methylnaphthalene

500/39/1.9

10/27

5.6 xlO4



SW-8015

TPH-d

500/220/940

500/400

2.2 xlO6

Notes:

Source: (DOH 2017) Hawaii Department of Health Environmental Action Level Surfer (Fall 2017)
a Soil EALs = (Gross Contamination) / (Direct Exposure) / (Leaching to Groundwater) in milligrams per
kilogram (mg/kg)

bGroundwater EALs = (Odor Taste Threshold)/(Drinking Water Toxicity)

cSoil Vapor EALs = Commercial /Industrial Shallow Soil Vapor Action Levels (Table C)

9

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

4.0	Phased Site Characterization Plan

This Site Characterization Plan uses a phased approach to conduct the site characterization, which
will include activities within the Adit 3 tunnel and the Pearl Harbor tunnel (in-tunnel
characterization) as well as activities external to the tunnels. It is expected that in-tunnel
characterization and external characterization will occur concurrently.

It is anticipated that additional phases will be added to this Site Characterization Plan once these
initial data gathering events are completed and the data have been evaluated by the Navy and
regulatory agencies.

4.1	In-Tunnel Characterization

In-tunnel characterization includes but is not limited to the following activities.

4.1.1 Geophysical Characterization of Shallow and Deep Subsurface Features

Ground-penetrating radar (GPR) will be used to clear the subsurface for utilities prior to ground
disturbance activities. GPR and surface electrical resistivity (ER)/induced polarization (IP) will be
used to locate the drainage system, identify subsurface fractures (which may facilitate LNAPL
downward migration and inform the location of the deeper soil vapor locations), and potentially
identify pooled LNAPL in the vadose zone.

The data quality objectives (DQOs) for the geophysical surveys are:

1.	Provide continuous data describing conditions in the fractured and heterogeneous basalt
between the Adit 3 and Pearl Harbor tunnel surfaces and the underlying water table

a.	Resolution should approach 10-15% of the mapping depth.

b.	Additional resolution is anticipated for bore hole ER/IP imaging for boreholes
closer than 50 ft from each other.

c.	Use of multiple assessment tools (GPR, ER, IP) along with soil vapor and
continuous coring will provide multiple lines of evidence to identify structural and
material differences of importance through-out the mapped subsurface.

d.	Material to be mapped include, but not limited to LNAPL, dense rock, porous rock,
void spaces, water-filled vs fuel-filled pores and fractures.

2.	Surface geophysics will be conducted over a period of weeks and will provide a snapshot
in time of the subsurface conditions:

a.	Stable conditions, such as rock characteristics (density, porosity) will not change
over time, and single measurements will fulfill requirements.

b.	Changing conditions (such as LNAPL migration and moisture content) will vary
over time and synoptic measurements will not identify these temporal trends.

10

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

3. Optional uses of ER/IP to include evaluation of changing conditions would include the
option of leaving the electrodes in-place over a period of time and would include periodic
data gathering, at significant points in time. These could include:

a.	Semi-permanent surface ER/IP array (s) whose construction and capabilities would
be similar to the ER/IP array described in Section 4.1.1.2.

b.	Semi-permanent downhole arrays that could be installed in tunnel borings that
would allow two-dimensional (2D) mapping of properties at depth with resolution
similar to that of the surface ER/IP.

GPR and ER/IP are geophysical methods that can potentially identify specific properties of the
fuel that are different from the host rock:

•	The GPR method maps changes in the dielectric permittivity of the subsurface. Dielectric
materials include polarizable molecules such as water, ethanol, and other hydrocarbons.

•	The ER/IP method maps the bulk resistivity of the subsurface including the rock, pore
space, and materials that fill the pore space, such as water and fuel. When combined with
the IP method, materials that can store electrical charge can be identified. Some organic
compounds can store charge and be mapped in space to potentially allow us to discern
where the fuel may be traveling through the subsurface.

4.1.1.1 Ground-Penetrating Radar

GPR uses high-frequency radio waves, typically in the range of 10-2,000 megahertz (MHz), to
image subsurface structures and features. A transmitter-antennae emits electromagnetic energy
into the subsurface. When this energy encounters an interface between materials with differing
permittivity, part of the energy is reflected back to the surface. A receiving-antennae records the
variations in the return signal. The signals are plotted in real-time as distance versus travel time
allowing an assessment of the results as the survey progresses. If the site allows, 2D profiles
(Figure 3) will be combined into a three-dimensional (3D) grid of data to assess the structure,
geology, or fuel location in plan-view as depth slices (Figure 4). Figure 4 shows example
subsurface linear anomalies representing transfer pipelines with warmer shades (yellow to red)
indicating leaking fuel (LNAPL).

Figure 3: Example 2D GPR Profile for a Lithology Mapping Survey Along a River Channel
Using a 100-MHz Antenna (m = meters).

11

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Depth = 0.495 feet Depth = 1.1 SO feet Depth - 1.815 feel Depth = 2.475 feet Depth = 1.135 feet Depth = 3. f95 feet

| '80 |

1:

I

0 10 20
Distance (feet)

f >80 I

0 10 20
Distance (feet)
Depth = 4.455 feet

320

320

-
ft

s

I

I o

0 10 20
Distance (feet)



I 180 I

I 180

I 180

0 10 20
Distance (feet)
Depth' 5.115 feet

0 10 20
Distance (feet)
Depth - S.775 feet

0 10 20
Distance (feet)
Depth ' 6.435 feet

0 10 20
Distance (feet)
Depth = 7.095 feet

0 10 20
Distance (feet)
Depth = 7.755 feet

320



370



320

r fl

320 |B



V 1









¦A

300
280



300
280

|

300
280

U

zs§

260

}

260

ay

260



¦

240

S

240



240

p.

1



it



,-ir







KB



200

200



200

f >80

L

j 180



I 180

hi

?-n

I 160

° 140



l 160

140



l IW

140



1

120
100

j

120
100



120
100





N



-

X,

80 1

i

f



60

¦

60

V

60

i

, 1

•E

40

20
0

33

40

20
0



40

20
0 1

-5

40



0 10 20
Distance (feet)

0 10 20
Distance (feet)

0 10 20
Distance (feet)

0 10 20
Distance (feet)

Figure 4: Example Combined 3D Grid of Data from Individual 2D Profiles

Subsequent office-based analysis will be conducted to allow for complex data filtering and
processing techniques that are not readily accomplished under field conditions. All GPR data
processing will be performed using the Ekko Project software (Sensors and Software, Mississauga,
ON, Canada), which allows for a variety of enhancement filters to reduce noise within the data
while drawing out GPR targets.

Signals from GPR can also be analyzed for frequency content to determine dispersion. Some
materials may preferentially absorb specific frequency bands, potentially leaving behind a unique
footprint to help determine the presence or absence of the fuel or its degradation products.

12

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

An example GPR system is illustrated on Figure 5.

Figure 5: GPR pulseEKKO PRO System, with 50-MHz Antennae Frequency

GPR Logistics and Limitations:

•	The electrical conductivity of the subsurface and the transmitter frequency are the primary
controls on the penetration depth of the GPR signal. Hence the penetration depth of the GPR
signal can be limited at project sites depending on the underlying surficial and geological
materials and moisture content, which control the electrical properties of the subsurface.
Lower transmitter frequencies have been chosen to improve the penetration depth; however,
conductive subsurface materials such as fine-grained sediments in the thin surficial cover or
high moisture contents can severely reduce the GPR signal and reduce imaging depths.

•	Survey locations must be clear of obstructions and allow free movement of the GPR
equipment within the survey area; therefore, areas covered by structures, aboveground
pipelines, materials, etc. will not be surveyed.

•	It is assumed that GPR data gathering lines will be conducted between the rails and beside
the rails in the tunnel to provide two profiles for each frequency.

GPR Survey Design:

13

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

The GPR survey will be conducted using two data collection survey lines paralleling each other
inside the tunnel: one between the rails and one outside the rails. GPR data will be collected in a
step-wise procedure along the approximately 1,000-ft length of the two survey lines. Each survey
line will be collected using the 50-, 100-, and 200-MHz antenna frequencies, producing a total of
six profiles. Use of variable low to high frequency signals allows for:

•	Low frequencies provide lower resolution information at greater depths bgs.

•	High frequencies provide higher resolution information at lesser depths bgs.

Actual depths are site-specific but anticipated to range between 4 ft bgs and 30 ft bgs.
4.1.1.2 Electrical Resistivity and Induced Polarity

In general, ER and IP is the science of measuring the electrical properties of the subsurface, with
the goal of using those properties to help characterize structure and properties of rocks and
sediments and their pore fluids. ER and chargeability (IP) are volumetric properties that describe
the resistance of electrical current flow within a medium and the ability of a material to hold an
electrical charge, respectively. Direct electrical current is propagated in rocks and minerals by
electronic or electrolytic means. Electronic conduction occurs in minerals where free electrons are
available, such as the electrical current flow through metal. Electrolytic conduction relies on the
dissociation of ionic species within a pore space. With electrolytic conduction, the movement of
electrons varies with the mobility, concentration, and the degree of dissociation of the ions.
Mechanistically, the resistivity method uses electric current (I) that is transmitted into the earth
through one pair of electrodes (transmitting dipole) in contact with the soil. The resultant voltage
potential (V) is then measured across another pair of electrodes (receiving dipole). When the
electrical current is turned off, the voltage decays slowly, which is a measure of chargeability.

ER and IP surveys are most reliable as a first-order target recognition tool. In this mode, sufficient
background data are required to distinguish the entirety of the target and confirm the extent of its
edges. A target cannot be identified if the variations in properties of the background material are
similar in contrast and scale to those associated with the target. Assuming the target can be
identified, the next order of interpretation is the relative degree of target size and intensity of the
signal (Figure 6).

14

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

South

Approx. Gasoline Spill Area

North

20

a;



®

u. 0

Q.

01

a -20

-40

(18ft E)	(22ft E)	(16ft E)

(15ft E)	(14ft E)

7	9 10 8	6

*

U.J

20

20

Line 1

40

60

80

180

100 120 140 160
Distance (Feet)

General Location of Highway 21

200

220

240

260

(4ft W) (6ft W)

(5ft W) (4ft W) (4ft W) (5ft W)



4 2

1 5 3 11

I III





1













Line 2

40

60

80

100

120 140 160
Distance (Feet)

180 200

220

240 260

120 140 160
Distance (Feet)

100 120 140 160
Distance (Feet)

LEGEND

I Well - No gasoline present
1 Well - Gasoline present

Log Resistivity (ohm-meters)

1.7 1.9 2.1 2.3 2.5 2.7 2.9 3.1

More Conductive

3.3 3.5
*¦

More Resistive

Figure 6: Electrical Resistivity Imaging from a Fuel Tanker Spill

15

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Data Collection Equipment

Data will be acquired using a Supersting R8 multichannel ER system (Advanced Geosciences, Inc.
| AGI], Texas). The Supersting is commonly used in surface geophysical projects and has proven
reliable for long-term, continuous acquisition. The meter is powered by an external 12V battery
with a maximum rated output current and power of 2 amps and 200 Watts, respectively. The
electrodes consist of 24-inch-long steel rods, which are typically installed 12-18 inches into the
ground using a small sledgehammer. Multi-electrode systems such as the Supersting allow for
automatic switching through pre-programmed combinations of four electrode measurements.
Figure 7 shows illustrations of example ER and IP equipment and setup.

¥. JL*	\ III III III I IWHWIWli II

Resistivity survey cable is laid out by hand.	Electrodes (-12 inch steel rods) are installed into

ground every ~ 10 feet connected to cable via takeout

Cables are con netted to the resistrvity meter
(yellow box), which is powered by 1 TV car
battery, and data collected

Figure 7: Supersting R8 Multichannel Resistivity System, Survey Equipment, and Features
ER and IP Data Analysis & Visualization

Measurements of subsurface ER with ER systems inevitably contain errors from a variety of
sources, including poor electrode contact, random device errors, and external effects. HGI, the
selected geophysical subcontractor for the project, has a vast array of experience collecting

16

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

resistivity data in challenging environments and has developed a number of data quality assurance
database templates to assist in assessing and editing these errors. Their process of data editing
identifies and eliminates erroneous data points, but no data modification (rounding, averaging,
smoothing, or splining) is performed.

The recorded raw resistivity data are downloaded each day for analysis, and a number of important
diagnostic data parameters are used to eliminate poor quality data. These include repeat errors on
the stacking performed during data collection, voltage/current (V/I, or transfer resistance, in ohms),
voltage (volts), and electrical current (amps) output. The goal is to find and remove spurious points
that do not conform to the data population or points that violate potential theory. The aim is to
remove data outside of the statistical population, such as measurements with negative or very low
V/I, low voltage, low current, or high apparent resistivity or geometrical factor are removed from
the data set.

The edited data set is subsequently inverted using 2D inversion software, RES2DINV (Geotomo
Software). RES2DINV is considered an industry standard for modeling ER data, and there are
many examples in the literature that show results from the code.

Data quality will be assessed in the field prior to demobilization from the site, and final 2D
inversions will be performed after positional information has been incorporated. The resulting
inversion output data will then be gridded and contoured using 2D visualization software (Surfer
or Geosoft).

Figure 8 shows an example of collecting resistivity inside a concrete-lined tunnel, where low
resistivity values were associated with seepage into the tunnel.

m

74*00 80*00	90*00	<00*00	110*00	120*00	130*00	140*00	150*00	160*00	170*00	180+00

I 1 i I 1 i i 1 i i i i I

|'J'	¦ {]'	W" ' YifF

IEW TUNNEL OLD TUNNEL I

ii'i L4Jlfc I iii » Hi i

7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 15500 16000 16500 17000 17500 18000

OtsUrtc* (ft)

vertical exaggeration 10;1

log Resrslivity (ohm-ft)

— I I

0 04 03 1 2 1.6 2 24 28 32 36 4 4.4

Figure 8: Electrical Resistivity Acquisition Inside a Tunnel

17

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Electrical Resistivity and Induced Polarity: Logistics and Limitations

•	Poor electrical contact (high contact resistance) between the electrodes and the ground can
affect the data quality in ER surveys. High contact resistance on electrodes is typically
caused by low moisture content (dry) of near-surface soils and materials and can be
remedied by watering the electrodes to reduce the resistance.

•	The installation of electrodes will require access holes to be drilled through the concrete
lining of the tunnel floor and into the surrounding bedrock. The access holes should be
1 inch in diameter and penetrate 4-6 inches into the bedrock to ensure good electrical
contact with the natural formation.

•	If present, metallic infrastructure in the subsurface, such as metal well casings or pipelines,
can cause interference in the ER measurements. Knowing the location of such
infrastructure in advance can often enable the survey lines to be positioned to avoid this
interference or be designed to minimize the effect on the measurements.

•	It is assumed that the survey lines will be accessible along their length using a wheeled cart,
as shown on Figure 8. If the tunnel does not allow for cart access or if the cart is prohibited,
this will likely reduce production rates if the equipment is required to be hand-carried in
from the closest road access.

Electrical Resistivity and Induced Polarity Survey Design

The survey resolution is controlled by the electrode spacing and electrode geometry (or electrode
configuration/electrode array). Based on the objectives of the survey, electrode spacing will be
approximately 10 ft (3 meters). While the horizontal resolution tends to decrease with imaging
depth (due to the required increasing electrode separation for deeper imaging of the technique),
this would ensure that the horizontal resolution would be of the order of 3-5 ft in the upper section
of the model results.

In addition, a modified Wenner electrode configuration will be utilized to increase resolution and
provide high signal-to-noise ratio. The vertical resolution, as with all surface-based geophysics,
will diminish with increasing depth and result in an anticipated vertical resolution on the order of
10% of the depth (e.g., at a depth of 30 ft, the maximum resolution would be on the order of 3 ft).

The imaging depth of a resistivity line is a function of the total length of the cable(s) deployed
during a single data collection event. This depth can be influenced by topographic changes along
the resistivity line, poor electrode contact, and extremely conductive or resistive subsurface
materials within the area of concern, but in similar surveys, the typical depth has been a maximum
of20-30% of the line length. The proposed survey line lengths are approximately 1,000 ft in length,
which will be designed to produce an imaging depth of approximately 200-250 ft below the tunnel
surface.

18

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Utility Clearance: Implementing the ER/IP survey will require approximately 150 1-inch-
diameter drill holes to be completed through the Adit 3 and Pearl Harbor tunnel concrete floors,
located at 10-ft intervals at locations identified on Figure 9. Prior to drilling these holes, the drill
areas will be cleared for underground utilities and rebar/wire mesh in the concrete using high-
resolution GPR. Locations cleared for drilling will be marked on the tunnel floor with red
construction crayon.

Drill through Concrete Slab: A hammer drill with a 24-inch extension 1-inch-diameter drill bit
will be used to drill through the concrete tunnel floor at the 120 cleared locations, which will be
preferentially located between the rails of the railroad track. Drill holes will pass through the tunnel
floor (between 8 and 16 inches thick) and approximately 4-6 inches into the underlying substrate,
but preferably into the native basalt. Drill holes will be sealed following their completion to prevent
fluids from passing through. As discussed in the DQO section, this will allow a resolution of
approximately 10% of the depth imaged:

•	At 10-ft depth below the tunnel floor, approximately 1-ft resolution is expected.

•	At 80-ft depth below the tunnel floor (the basal water table), approximately 8-ft resolution
is expected.

Installing Electrodes: Metal electrodes will be hammered into the substrate with a stickup of less
than 1 inch above the concrete floor of the tunnel and will be connected with cabling, as shown on
Figure 7.

Data Gathering: Data gathering will be completed over 24-72 hours.

Drill Hole Abandonment: All drill holes will be filled with Portland cement concrete and finished
flush to the initial tunnel floor surface. Final drill hole abandonments will be completed so that no
liquid will pass through them into the native environment.

4.1.2 A ddition al Surface S VMP Installation an d Sampling

Figure 10 provides a conceptual presentation of the expected location of tunnel activities that will
occur following the geophysical surveys, including the additional SVMP locations.

19

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

ic a 8 e s w

rn m m W fN N

10 S rt 8

2 2 fC

w ® KJ 8 «

Units of feet froni the origin

§ a § s § a 8

a s §

<











*4 • • A • • • • • • •

• • « t I •





PV-



I SUMP |



*



% 1



[

To Adit 3











\



Estimated Location of
6" Hume drain -

Door

To Red Hill Bulk Fuel Storage Facility

8 w S W 8 S

l7l	*?	*7	T	fn

\

isolation
Door

Legend

TwoGPR Lines

ER/IP electrode

Spacing (approx. 10 ft) ••••••

Surface Soil Vapor Pins A A A A

Figure 9: Geophysical Survey Design

Note:

Due to extreme activity in the pump station associated with preparing the US Navy Well 2254-01
for operation to discharge, work associated with the pump station will occur when practical.

20

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

2'x2' concrete	Summa -TO3,

Slab cut and	T015 C02,

removal to	Methane, 02
uncover Hume /
Drain

I	/

/

Summa -T03,
T015 C02,
Methane, 02

Units of feet from the origin
2'x2'
concrete
Slab cut and
removal to
uncover
Hume Drain



Summa -T03,
T015 C02,
Methane, 02

2'x2'
concrete
Slab cut and
removal to
uncover
Hume Drain

I

Summa -T03,
T015 C02,
Methane, 02

nstall SVMP to
3'-5 ' depth InfB
1" core hol<

SUMP

Rails

To Adit 3

Estimated Location of
6" Hume drain

Install SVMP
3'-5' depth
1" core hoi

Five additional
SVMPs at 25 ft
intervals

To Pump Station

Five additional
MPs at 50 ft

S

ntervals



$5?







Isoiati
Door

Summa -T03,
TOIS C02,
Methane, 02

2'x2'

concrete	

Slab cut and
removal to
uncover
|ume Drain

A-

sffl

Isolation

Door	To Rec

.



To Red Hill Bulkfuel
Storage Facility)

svm!

j VIVII

additional
Ps at 50 ft

intervals



\

NT,

\

a nstail SVMP
3'-5 ' depth
1" core holi

IP to

h in

I

LEGEND
> 150ppmv
80 -150ppmv
50 - 80ppmv
25 - 49 ppmv
13 - 24 ppmv

Figure 10: General Layout of Characterization Activities in the Tunnel

Note:

Due to extreme activity in the pump station associated with preparing the US Navy Well 2254-01
for operation to discharge, work associated with the pump station will occur when practical.

21

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

4.1.2.1 Data Quality Objectives and Regulatory Drivers
The DQOs for the SVMP surveys are:

1.	Provide a semi-quantitative and quantitative first-phase evaluation tool to identify areas
of the shallow bedrock subsurface and utility corridors that have been impacted by JP-5:

a.	In addition to the 47 SVMPs installed in December 2021, five additional SVMPs
will be installed at the end of the impacted areas to identify the extent of the release
using semi-quantitative hand-held continuous read-out detectors. Calibrated hand-
held organic vapor detectors, such as PIDs, will be used to provide timely
measurements of relative concentrations, although calibration gas (isobutylene)
will not accurately provide exact petroleum hydrocarbon concentrations.

b.	SVMPs will be sampled for laboratory analysis to provide information about the
constituents within the complex JP-5 mixture to inform the degree of saturation and
degradation within the subsurface.

2.	Provide a longer-term trend evaluation tool. SVMPs can be monitored over time to
evaluate changes in conditions at each location, which can support assessment of LNAPL
migration and degradation over time (contaminant fate and transport), which in turn can
be used for modeling.

Regulatory drivers for the SVMP surveys are presented in the DOH TGM and LNAPL Guide in
Section 3.0.

SVMP Locations and Naming Convention

Two additional subslab SVMPs will be installed at the eastern end of the existing Adit 3 SVMP
locations, which currently end at A3-400, located approximately 900 ft from the entrance to Adit 3.
Two SVMPs will extend at 50-ft intervals using the following naming system:

•	SVMP A3-450 will be located 50 ft east of A3-400 between the rails on the northern edge.

•	SVMP A3-500 will be located 100 ft east of A3-400 between the rails on the northern edge.

Two additional subslab SVMPs will be installed at the southern end of the existing Pearl Harbor
tunnel SVMP locations, which currently end at S2-225, located approximately 225 ft from the
Adit 3 tunnel merge with the Pearl Harbor tunnel. Two SVMPs will extend at 50-ft intervals using
the following naming system:

•	SVMP S2-275 will be located 50 ft east of S2-225 between the rails on the eastern edge.

•	SVMP S2-325 will be located 100 ft east of S2-225 between the rails on the eastern edge.

22

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

If necessary, one additional SVMP is scoped to be installed at either the east end of the Adit 3
array or the southern end of the Pearl Harbor tunnel array, based on the concentrations measured
at the final SVMP locations. If necessary, additional SVMPs will be installed in later phases.

Due to intense activity associated with ongoing cleanup of the U.S. Navy Well 2254-01 water
development tunnel, some important areas associated with the Pump House may not be available
for subslab soil vapor assessment at this time. These assessments will be considered for future
phases.

SVMP Installation and Sampling Procedures

1)	SVMP locations will be identified using GPR to identify the thickness of the concrete and
avoid utilities and rebar. At each SVMP location, the SVMP will be installed through the
tunnel floor approximately 1 ft from the tunnel wall or any tunnel wall obstruction.

2)	Concrete drilling will be conducted at each location (6-inch depth or greater anticipated):

-	Concrete drilling will be conducted using a concrete hammer drill using 120-volt
alternating current (VAC) power source.

-	The drill hole will be moistened with small amounts of water to mitigate sparking and
will be continuously removed with a high-powered vacuum during drilling.

-	The drilling area will be monitored using a lower explosive limit (LEL) meter to ensure
that conditions never exceed the LEL during drilling.

-	Drill holes will be monitored during drilling to ensure the integrity of the concrete slab.
Any cracks in the slab will be repaired to Navy specifications.

-	Any drill holes that are not used for any reason will be abandoned per Item 6 below
before mobilizing off site.

3)	Up to five new SVMPs will be inserted into the concrete core holes per the attached
Standard Operating Procedures (SOPs) (Appendix C):

-	SVMPs will be flush-installed as to not create a tripping hazard and will be located
along the edge of the access tunnel to avoid traffic.

-	SVMPs will be sealed with a water-tight stainless steel cap to ensure that no liquids
can migrate into the subsurface through the SVMP. The SVMP will also be capped to
ensure that no migration through the pin is possible when they are not being used.

4)	The new SVMPs will be sampled weekly with the existing SVMP network with Tedlar
bags and hand-held direct readout instruments (PIDs) in accordance with the attached SOPs
(Appendix C).

5)	Three to five SVMPs will be sampled via Summa canisters monthly, to be analyzed by the
contract laboratory. Laboratory samples will be analyzed for total volatile organic
compounds (VOCs) by TO-3, individual VOC constituents by TO-15, and methane.

23

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

6) SVMPs will be properly abandoned when the U. S. Navy determines that they are no longer
useful. The drill holes will be filled with traffic-rated cement with sand aggregate to tunnel
surface and finished to the specifications of the original concrete floor.

Activity inside the Adit 3 and Pearl Harbor tunnels may encounter organic vapors. These vapors
are likely associated with jet fuel released during the November 20, 2021 release. During all
activities, the breathing zone will be monitored for organic vapors using a PID.

4.1.3 Near-Surface Intrusive Assessment

4.1.3.1 Data Quality Objectives and Regulatory Drivers
The DQOs for the near-surface intrusive assessments are:

1. Provide a semi-quantitative and quantitative first-phase evaluation tool to identify areas
of the shallow bedrock subsurface and utility corridors that have been impacted by JP-5:

a.	In hotspot areas, the tunnel floor will be removed to verify the existence and
construction of the Hume drain and associated utility corridor using semi-
quantitative hand-held continuous read-out detectors. Calibrated hand-held organic
vapor detectors, such as PIDs, will be used to provide timely measurements of
relative concentrations, although calibration gas (isobutylene) will not accurately
provide exact petroleum hydrocarbon concentrations.

b.	The Hume drain will be assessed and if practical, a drain video will be run through
the portion of the pipe that is accessible at each opening.

c.	Samples will be collected of the surface soil (0.0-0.5 ft) within each cutout using
multi-increment sampling (MIS) methodology to provide a MIS result for each
cutout as a decision unit (DU). In one cut-out, MIS sampling will consist of three
replicate samples. Each MIS sample will consist of 30 subsamples. MIS samples
will be analyzed for:

i.	Benzene, toluene, ethylbenzene, xylenes (BTEX) and TPH-gasoline (-g) by
SW-846 Method 8260

ii.	Naphthalene, 1-methylnaphthalene, and 2-methylnaphthalene by SW-846
Method 8270

iii.	TPH-d and TPH-oil and residuals (-o) by SW-846 Method 8015 Modified
Action levels will be associated with potential leaching to drinking water, as described in

iv.	Table 3-2.

Figure 10 presents the anticipated locations of the near-surface intrusive assessments. Two to three
2-ft x 2-ft concrete squares will be cut within the middle of the Hume line in close proximity to
the point of release at the end of the SVMP locations within Adit 3, near the sump, and the Adit 1
hot spot (near Adit 1 and 3 intersection). The purpose of this effort is to have a better understanding

24

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

of the drainage system and observe the presence of LNAPL pooling and/or seeping into the
subsurface.

Surface soils (0.0-0.5 ft below surface) will be visually documented (e.g., level of soil staining),
and a MIS sample will be collected for total VOC analysis using a PID.

4.1.4 Shallow, Intermediate, and Deep Subsurface SVMPs

Three shallow subsurface SVMPs locations and one Intermediate and deep nested SVMP will be
installed during this phase of the characterization.

4.1.4.1 Shallow SVMPs

Three shallow-subsurface SVMPs will be installed up to 5 ft bgs at the following locations:

•	Near the sump (if logistics allow)

•	At the point of release

•	At the hot spot location within Pearl Harbor Tunnel (overlying the water development
tunnel)

The purposes of these subsurface SVMPs are to:

•	Validate whether concentrations are higher at depth.

•	Track weathering and degradation of the LNAPL.

•	Assess LNAPL saturation within the subsurface matrix.

These shallow subsurface SVMPs may be installed in locations identified in the concrete cut-outs
described in the near-surface intrusive assessment presented in Section 4.1.3 or may be installed
as separate 0.5-inch drill holes in the vicinity of these hotspot cutouts, depending on conditions
encountered in the field. Each SVMP will include a temperature probe in the vicinity of the SVMP
influent (screen).

To measure natural source-zone depletion (NSZD) rates within the subsurface formation, thermal
couple temperature probes will be installed adjacent to the SVMPs to measure the heat signatures
within the subsurface. These heat readings can be directly converted to biodegradation rates. This
will support degradation information from the laboratory soil vapor results, quantify LNAPL
degradation (i.e., gallons per day), and inform selection of future remediation. Measuring
temperature at a variety of depths below the tunnel floor will be used to provide qualitative
evidence of NSZD.

The purposes of installing shallow subsurface SVMPs and temperature probes are to characterize
petroleum impacts within the shallow basalt below the base of the tunnel subfloor infrastructure
and to evaluate biological source-zone depletion, which involves exothermic reactions that

25

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

generate heat. The shallow subsurface SVMPs and temperature probes should be installed at a
depth of at least 1 ft into the basalt. Generally, the shallow SVMPs and temperature probes will be
installed at a depth of 5 ft below the tunnel floor; however, this depth may be adjusted if additional
informati on is obtained regarding the thi ckness of the subfloor infrastructure.

Boreholes for the shallow subsurface SVMPs and temperature probes may be installed using either
a hammer drill, jack hammer with extension, or a coring instrument. The choice of equipment may
depend on the availability and the importance of obtaining a sample core to evaluate shallow
geology. The construction of these shallow subsurface SVMPs and temperature probes is presented
on Figure 11.

4,1.4.2 One set of Nested Intermediate and Deep SVMPs

As the final phase of the current characterization within the tunnels, intermediate and deep SVMPs
and temperature probes will be installed in a single boring location, anticipated to correspond
with hotspots identified by prior phases (i.e., geophysics, subslab SVMP measurements, and near-
surface intrusive assessments). The construction of these nested SV MPs and temperature probes
is presented on Figure 11.

These deeper subsurface SVMPs will require an electric coring rig, such as the Hagby ONRAM
1000 or similar.

HumeC

rain Corridor

1

10-ft SVMP/TP
/ 15-ft SVMP/TP

/



Nea r Surface SVMP/TP
\



V /75-ft SVMP/TP Nested SVMP/TPs



\





/





Tl1 o ¦









MAPI :>

















1



































2.5"







0	5	Scale in Feet	10	15	20

Figure 11: Schematic of Single and Nested SVMPs

26

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

Materials

•	SVMPs:

-	1-inch stainless steel soil vapor implant (available from EPS, https://www.shop-
esp.com/All-Implants-C355.aspx)

-	Vs-inch tubing. Copper or steel tubing is recommended for consistency with the below-
tank SVMPs.

-	H-inch ball valve with 3/i6-inch hose barb

-	Swagelok hardware for connection of SVMP tubing to ball valve and hose barb

-	Sand (US Mesh 20-40)

-	Bentonite

•	Temperature Probe:

-	Physitemp temperature probe with 0.1 degree Celsius (°C) accuracy (e.g., PT-6-6 ft)
(www. phy sitemp .com)

-	Note - it may be possible for Physitemp to make custom probes that are more cost-
effective than the IT-18-10 ft)

-	The temperature probes can be read with a BAT 12 thermometer. AECOM has a BAT 12
thermometer that was purchased from the 2017/2019 NSZD study.

SVMP Completion

The SVMPs should be completed as shown on Figure 11.

SVMP Sampling

SVMPs will be sampled weekly with Tedlar bags and hand-held direct readout instruments (PID)
in accordance with the attached SOPs (Appendix C).

Three to five subsurface SVMP/temperature probes will be sampled via Summa canister monthly,
to be analyzed by the contract laboratory. Laboratory samples will be analyzed for total VOCs by
TO-3 and for individual VOC constituents by TO-15, as well as oxygen, carbon dioxide, and
methane.

•	Field Equipment:

-	RAE System ppbRAE Plus PID (instrument currently used for monitoring program),
or equivalent instrument

-	RAE System Multi-RAE, or equivalent instrument capable of measuring oxygen, and
carbon dioxide.

27

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Sampling Materials:

-	Summa canisters for sample collection plus spare canisters, all batch or individually
certified clean

-	200 milliliter (mL)/minute flow controllers

-	Hardware and materials to connect the Summa canisters to the SYMPs (see Figure 12).

Summa Canister

Swagelok Connection

\

Nylon or Teflon Tubing
Zip Ties

Masterflex Tubing

(2 sizes, if needed}

Hose Barb from Soil Gas Well

Figure 12: Illustration of Connection between SVMP and Summa Canister

SVMP Sampling Procedures

Field Screening: All SVMPs will be testing using the field instruments (PID and landfill gas
meter):

•	Total VOC Concentration: Use the PID to measure concentrations of total VOCs
concentration in accordance with the attached SOPs (Appendix C). The minimum purge
volume prior to sample collection should be 1 liter.

•	Oxygen and Carbon Dioxide: Following completion of PID measurements, use the Multi-
RAE (or equivalent meter) to measure oxygen and carbon dioxide concentrations in
accordance with the instrument operating manual. Ensure that a new charcoal filter
cartridge is installed in the sample line between the water filter and the instrument, A new

28

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

(i.e., previously unused) filter should be suitable for one round of sampling (all sample
points and all tanks).

•	The Multi-RAE gas meter reading can be collected from the same Tedlar bag used for the
PID reading. The landfill gas meter requires approximately 400-600 mL of sample for
purge and reading. The Tedlar bag may need to be refilled if sufficient volume is not
available after the PID measurement.

•	Differential Pressure: After collection of the PID sample, use Multi-RAE Meter (or
equivalent meter) to measure differential pressure between each SVMP and the tunnel.
Connect the meter to the SVMP in accordance with the instrument operating manual. Open
the ball valve on the SVMP. Take the pressure reading in accordance with the instrument
operating manual.

Sample Collection: A Summa canister (with 200 mL/min flow controller) sample can be collected
from select SVMPs based on PID readings. The sampling could be completed as follows:

•	Selection of SVMPs: Review the PID readings and select an SVMP from each area of high
PID readings indicative of a potential hot spot. Select additional SVMPs in areas of lower
PID readings to characterize areas with potentially lesser impacts.

•	Summa Canister Sample: If the ball valve on the SVMP has remained closed since filling
the Tedlar bag, then the point should not require any additional purging. Connect the
Summa canister to the SVMP (e.g., as shown on Figure 12). Open the ball valve on the
SVMP and then open the valve on the Summa canister. Leave the valves open until the
canister vacuum falls to less than 5 inches mercury (Hg) or for a maximum of 15 minutes
to allow the Summa canister to fill. Close the Summa canister and ball valve and disconnect
the Summa canister.

Laboratory Analysis

The Summa canister samples should be shipped at ambient temperature under chain of custody
(CoC) control to the selected laboratory. For consistency with prior Summa canister sampling at
the Facility, it is recommended to use either Alpha Analytical, Westborough, MA, used for a 2017
Red Hill natural source-zone depletion (NSZD) study (DON 2019) and 2021 baseline sampling
conducted for the Red Hill Continuous Soil Vapor Monitoring Pilot System (DON 2021a); or
Enthalpy Analytical, Orange, CA, used for Notice of Interest monitoring for the May 6, 2021
pipeline breach (DON 2021b).

Samples should be analyzed for:

•	Volatile petroleum hydrocarbons by USEPA Method TO-15 (Enthalpy) or TO-15 PIANO
(Alpha)

29

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

•	Fixed gases (oxygen, carbon dioxide, methane, and nitrogen) by ASTM Method D-1946
or EPA Method 3C

•	Total petroleum hydrocarbons (TPH) by Method TO-3 or Method 8015
4.2 External Characterization

Site characterization external to the tunnels includes but is not limited to the following activities.
4.2.1 OWDF Leach Field Subsurface Characterization

Based on historical drawings, it is possible that JP5-impacted fluid from the Adit 3 sump may have
been transported via the Hume drain system to an external leach field, including first a holding
tank and then a leach tank located adjacent to the concreted portion of South Halawa Stream.

4.2.1.1	Background

On December 18, 2021, a buried holding tank and connected leach tank was identified. The
purpose of these tanks is to discharge storm water collected from the sump pump located at the
entrance of Adit 3. Both cylindrical tanks are 8 ft tall and 7 ft in diameter. Upon inspection of the
holding tank, approximately 1,500 gallons of fuel/water mixture was identified. This fuel/water
mixture was pumped out of the tank and measured to contain approximately 253 gallons of free
product and roughly 1,250 gallons of water. The leach tank was empty and completely dry;
however, noticeable petroleum odors were observed. At this time, it is unknown whether these
petroleum odors are a result of volatized fuel vapors that traveled from the holding tank or fuel
that may have entered the leach tank. This proposed approach seeks to address this uncertainty and
support decision-making regarding a remedial action, if needed. The location of the holding tank,
leach tank, and sampling locations is illustrated on Figure 13.

The DQOs for the leach field subsurface characterization are:

•	Determine whether petroleum and/or petroleum-impacted water was/is entering the
holding tank and leach tank from the Adit 3 drain line.

•	Determine whether petroleum and/or petroleum-impacted water was/is passing through the
holding tank and leach tank from the Adit 3 drain line and into environmental media
(subsurface soil, groundwater) in the vicinity of these features.

•	If petroleum impacts have entered the environment adjacent to these features, determine
the nature and extent of the contamination.

4.2.1.2	Pre-intrusive Work Requirements
Prior to advancing soil borings:

•	The Navy will be provided with completed dig permits for each potential intrusive activity,
as described in the SOPs (Appendix C).

30

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

•	A proper opening in the security fence along the property perimeter must be installed and
monitored while open to potential trespassers.

•	Each potential boring location must be cleared by utility-clearing methods, or hand or air-
knife excavated to 5 ft bgs before direct-push coring can commence, as described in the
SOPs (Appendix C).

4.2.1.3 Subsurface Soil Sampling Step-out Strategy

A direct-push drill rig will be used to collect soil cores from surface to 15 ft bgs initially at four
locations surrounding the perimeter of the holding tank (HT) and leach tank (LT). These locations
will be 5 ft from the edge of the tank along the modified north, south, east, and west directions to
focus on the topographic gradient and impact to South Halawa Stream.(see Figure 13). If
petroleum-contaminated soil is observed at 15 ft bgs, borings will continue until contaminants are
not observed or until conditions (boulders, bedrock) make direct-push sampling unfeasible (refusal
or groundwater encountered).

If evidence of petroleum is observed in a borehole:

•	The boring will be advanced and continuously cored until there is no longer evidence of
petroleum, or until refusal.

•	The soil core will be screened via headspace analysis using the PID, and visual and
olfactory-based professional judgement.

•	A discrete soil sample will be collected of the most contaminated portion of the cores as
determined by associated headspace analysis and professional judgment and will be
analyzed for middle-distillate petroleum constituents as described in Table 3-1.

•	A discrete sample will be collected from the total depth of each core hole and analyzed for
middle-distillate petroleum constituents.

•	When sampling is completed in each borehole, that borehole will be abandoned as specified
in the SOPs (Appendix C).

•	Once a contaminated boring is completed, the sampler will step-out 15 ft in the associated
ordinal direction (north, south, east, west) and begin sampling in the location identified.

If evidence of petroleum is not observed in a borehole:

•	If the sampled borehole location is directly adj acent to the holding tank, the sampling team
will move to the next initial ordinal direction sampling location (located 5 ft from the
holding tank).

•	If the sampled borehole location is 15, 30, or 45 ft from the holding tank, the sampling
team will step-back 7.5 ft to the next sampling location.

- The next boring will be advanced and sampled following the strategy described above.

31

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

•	If the sampled borehole location is 7.5, 22.5 ft, or 37.5 ft from the holding tank, the
sampling team will move to the next ordinal sampling direction and continue with this
strategy until headspace indicates contamination has been delineated in each ordinal
direction.

Subsurface soil samples will be screened for petroleum constituents in accordance with the SOPs
for soil head space screening (Appendix C). If soil headspace is greater than 1 part per million by
volume (ppmv) and less than 5 ppmv (above ambient readings) and there is evidence of soil
contamination, or the PID reading is greater than 5 ppmv above ambient conditions, the soil will
be considered petroleum impacted and sampling will continue in that bore hole.

If contamination is not detected, one discrete sample will be collected at the total depth of the
boring.

Samples will be packed and shipped to the contract laboratory to be analyzed for:

•	Benzene, toluene, ethylbenzene, xylenes (BTEX) and TPH-gasoline (-g) by SW-846
Method 8260

•	Naphthalene, 1-methylnaphthalene, and 2-methylnaphthalene by SW-846 Method 8270

•	TPH-d and TPH-oil and residuals (-o) by SW-846 Method 8015 Modified

4.2.1.4 Holding Tank Investigation Subsurface Soil

A direct-push drill rig will be used to collect soil cores from surface to 15 ft bgs at four locations
surrounding the perimeter of the holding tank:

•	5 ft north of the edge of the holding tank along the centerline at location HT-N-5

•	5 ft south of the edge of the holding tank along the centerline at location HT-S-5

•	5 ft east of the edge of the holding tank along the centerline at location HT-E-5

•	5 ft west of the edge of the holding tank along the centerline at location HT-W-5

Subsurface soil sampling will continue following the step-out strategy described in Section 4.2.1.3.

32

-------
Site Characterization Plan

November 2021 Release, US Navy Well 2254-01

January 2022

Legend

j - 15, 30,45 ft radii
~% -15, 30,45, 60 ft radii

•	• Channelized Halawa Stream

•	Holding Tank

•	Leach Tank
Monitoring Well

Figure 13: Exterior Subsurface Soil Boring (Direct-Push) Sampling Layout

33

-------
Site Characterization Plan

November 2021 Release, US Navy Well 2254-01

January 2022

This page intentionally left blank

34

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

4.2.1.5 Leach Tank Investigation

The leach tank is located to the west of the Facility security fence and intrusive sampling using
mobile direct-push instruments will require access through the security fence, including the
temporary removal of fencing. This activity must be completed in accordance with Navy
requirements. The security fence must be operable during periods that are not monitored by
AECOM employees.

The leach tank investigation has two sequential parts: sediment sampling within the leach tank and
direct-push samples around the leach tank using the same step-out strategy defined in Section
4.2.1.3.

Currently, vegetation trimming (not removal) is proposed surrounding the leach tank to clear
vegetation for the proposed Large-Volume Treatment Plant. Since vegetation will be trimmed only
and not removed due to permitting requirements, the direct-push rig may not be able to collect
samples beyond the leach tank. If necessary, samples will be collected using hand augers in the
event the drilling rig cannot access sampling locations to due vegetation.

Leach Tank Sediment Sampling

To verify whether fuels may have entered the leach tank, one composited sediment sample will be
collected from sediments observed in the bottom of the leach tank and analyzed with a PID for
total VOCs. The composited sediment sample will be collected instead of the MIS sample due to
the limited sediments anticipated to be available in the tank and the difficult access to these
sediments. The composited sample will be packed and shipped to the contract laboratory following
SOPs (Appendix C) to be analyzed for:

•	BTEX and TPH-g by SW-846 Method 8260

•	Naphthalene, 1-methylnaphthalene, and 2-methylnaphthalene by SW-846 Method 8270

•	TPH-d and TPH-o by SW-846 Method 8015 Modified

Subsurface Soil Sampling in the vicinity of the Leach Tank

A similar step-out strategy will be used at the leach tank as described for the holding tank :

•	5 ft north of the edge of the leach tank along the centerline at location LT-N-5

•	5 ft south of the edge of the leach tank along the centerline at location LT-S-5

•	5 ft east of the edge of the leach tank along the centerline at location LT-E-5

•	5 ft west of the edge of the leach tank along the centerline at location LT-W-5

Subsurface soil sampling will continue following the step-out strategy described in Section 4.2.1.3.

35

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

5.0	Sample Details

Details of subsurface unconsolidated material samples are presented in Appendix B.

5.1	Sample Custody Requirements

Each sample will be assigned a CoC sample identification (ID) number and a descriptive ID
number in accordance with NAVFAC Pacific Environmental Restoration Program Procedure
I-A-8, Sample Naming (DON 2015). All sample ID numbers will be recorded in the field logbook
in accordance with Procedure III-D, Logbooks (DON 2015). The CoC sample ID number (the only
ID number submitted to the analytical laboratory) is used to facilitate data tracking and storage.
The CoC sample ID number allows all samples to be submitted to the laboratory without providing
information on the sample type or source. The descriptive ID number is linked to the CoC sample
ID number, which provides information regarding sample type, origin, and source.

5.1.1 CoC Sample Identification Number

A CoC sample ID number will be assigned to each sample as follows, to facilitate data tracking
and storage:

ERH = Designates the samples for the Red Hill Bulk Fuel Storage Facility
Groundwater Long-Term Monitoring program

xxx = Chronological number, starting with next consecutive number (will be

QC samples will be included in the chronological sequence.

5.1.2 Descriptive Identification Number

A descriptive ID number (for internal use only) will identify the sampling location, type, sequence,
matrix, and depth. The descriptive ID number is used to provide sample-specific information
(e.g., location, sequence, and matrix). The descriptive identifier is not revealed to the analytical
laboratory. The descriptive ID number for all samples is assigned as follows:

ERHxxx

Where:

determined prior to field work and is dependent on the last number used in the
most recent sampling event)

Aaaaaa-bbcc-dee-Dff.f

Where:

Aaaaaa

cc

bb

Site area (Table 5-1)

Sample type and matrix (Table 5-2)

Location number (e.g., borehole 01, 02, 03)

36

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

d	= Field QC sample type (Table 5-3)

ee = Chronological sample number from a particular sampling location (e.g., 01,
02)

D	= The letter "D" denoting depth

ff.f = Depth of sample in ft bgs (measured to the tenth of a foot). For water matrix
samples, the depth field will contain the month, day, and year of collection
(e.g., 021518 for February 15, 2018).

For example, the sample number RHMW11-BS01-S01-D20.0 would indicate that the sample is
the first sample collected from the first subsurface unconsolidated material location, encountered
at 20 ft bgs, from the borehole advanced for monitoring well RHMW11. The duplicate sample
would be designated as RHMW11-BS01-D01-D20.0. These characters will establish a unique
descriptive identifier that will be used during data evaluation.

Table 5-1: Area Identifiers

Identifier

Site Area

LF01

Leach Field

LT01

Leach Tank

HT01

Holding Tank

RA01

Release Area 1

PH01

Pearl Harbor Tunnel hotspot 1

AS01

ADIT 3 Sump 01

Table 5-2: Sample Type and Matrix Identifiers

Identifier

Sample Type

Matrix

BS

Subsurface Unconsolidated
Material

Unconsolidated Material

WQ

Water Blanks

Water

PW

Potable Water

Water

CO

Rock Core

Core

PR

Jet Fuel

Product

37

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Table 5-3: Field QC Sample Type Identifiers

Identifier

Field or QC Sample Type

Description

S

Primary Sample

All field samples, except QC
samples

D

Duplicate

Co-located for unconsolidated
material

E

Equipment Blank

Water

B

Field Blank

Water

T

Trip Blank

Water

A

Ambient Blank

Water

5.1.3 Handling, Shipping, and Custody

All samples collected for analysis will be recorded in the field logbook in accordance with
Procedure III-D, Logbooks (DON 2015). All samples will be labeled and recorded on CoC forms
in accordance with Procedure III-E, Record Keeping, Sample Labeling, and Chain-of-Custody
(DON 2015). Samples will be handled, stored, and shipped in accordance with Procedure III-F,
Sample Handling, Storage, and Shipping (DON 2015). All samples collected on this project will
be shipped to the analytical laboratory via overnight airfreight.

All samples received at the analytical laboratory will be managed in accordance with laboratory
SOPs for receiving samples, archiving data, and sample disposal and waste collection, as well as
storage and disposal per Section 5.8, "Handling of Samples" of the Department of Defense Quality
Systems Manual (QSM) v. 5.4 (DoD and DOE 2021).

5.2 Laboratory QC Samples

Laboratory QC samples will be prepared and analyzed in accordance with the methods and
procedures listed in Appendix B.

6.0 References

Department of Defense and Department of Energy, United States (DoD and DOE). 2021.
Department of Defense (DoD) and Department of Energy (DOE) Consolidated Quality
Systems Manual (QSM) for Environmental Laboratories. DoD/DOE QSM Ver. 5.4.
Prepared by DoD Environmental Data Quality Workgroup and DOE Consolidated Audit
Program Operations Team.

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785,
EPA-505-B-04-900A. In conjunction with the U.S. Environmental Protection Agency and
the Department of Energy. Washington, DC: Intergovernmental Data Quality Task Force.
March.

38

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

January 2022

Department of Health, State of Hawaii (DOH). 2017. Evaluation of Environmental Hazards at
Sites with Contaminated Soil and Groundwater, Hawai 'i Edition. Hazard Evaluation and
Emergency Response. Revised 2017. Fall.

	. 2018. Draft TGM Update, Section 9.3: LNAPL / Petroleum Guide.

https://health.hawaii.gOv/heer/2018/07/01/draft-tgm-update-section-9-3-lnapl-petroleum-
guide/.

	. 2021. Technical Guidance Manual for the Implementation of the Hawaii State

Contingency Plan. Interim Final. Honolulu, HI: Hazard Evaluation and Emergency
Response Office. November 12, 2008. Latest Update: July 2021.

Department of the Navy (DON). 2015. Final Project Procedures Manual, U.S. Navy
Environmental Restoration Program, NAVFAC Pacific. JBPHH HI: Naval Facilities
Engineering Command, Pacific. May.

	. 2019. Conceptual Site Model, Investigation and Remediation of Releases and

Groundwater Protection and Evaluation, Red Hill Bulk Fuel Storage Facility, Joint Base
PearlHarbor-Hickam, O 'ahu, Hawai 'i; June 30, 2019, Revision 01. Prepared by AECOM
Technical Services, Inc., Honolulu, HI. Prepared for Defense Logistics Agency Energy,
Fort Belvoir, VA, under Naval Facilities Engineering Command, Hawaii, JBPHH HI.

	. 2021a. Draft Work Plan, Continuous Soil Vapor Monitoring Pilot Test, Red Hill Bulk

Fuel Storage Facility Joint Base Pearl Harbor-Hickam, O 'ahu, HawaiPrepared by
AECOM Technical Services, Inc., Honolulu, HI. Prepared for Defense Logistics Agency
Energy, Fort Belvoir, VA, under Naval Facilities Engineering Systems Command, Hawaii,
JBPHH HI.

	. 2021b. Initial Release Response Report, Pipeline Breach in Tunnel Red Hill Bulk Fuel

Storage Facility JBPHH O 'ahu Hawai 'i. Prepared by AECOM Technical Services, Inc.
JBPHH HI: Naval Facilities Engineering Systems Command, Hawaii. September.

39

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

This page intentionally left blank

40

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

Appendix A - Project Schedule

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

This page intentionally left blank

-------
Last Updated: 1/2/2022 6:55 PM

Preliminary Schedule

November 20, 2021 Site Characterization

Type Task Name Start Date Finish Date

Holding Tank and Leach Tank Subsurface Soil Characterization



Preparation





Subtask

Subcontracting

Monday, January 3, 2022

Tuesday, January 10, 1900



Laboratory

Monday, January 3, 2022

Thursday, January 6, 2022



Utility Survey/Toning

Monday, January 3, 2022

Thursday, January 6, 2022



Direct Push Sampling Rig

Monday, January 3, 2022

Thursday, January 6, 2022

Subtask

Ground Truth Locations

Monday, January 3, 2022

Thursday, January 6, 2022

Subtask

Dig Permit

Monday, January 3, 2022

Tuesday, January 10, 1900

Subtask

Utility Survey/Toning/One call

Monday, January 3, 2022

Friday, January 7, 2022

Subtask

One Call

Monday, January 3, 2022

Friday, January 7, 2022

Subtask

Utility Survey/Toning

Monday, January 3, 2022

Friday, January 7, 2022











Field Work

Tuesday, January 10,1900

Tuesday, January 24,1900

Task

Site Preparation/Mobilization

Tuesday, January 10, 1900

Friday, January 13, 1900

Subtask

Vegetation Clearing

Tuesday, January 10, 1900

Friday, January 13, 1900

Subtask

Road/Drill Pad Construction

Tuesday, January 10, 1900

Friday, January 13, 1900

Subtask

Fence removal and Gate Install

Tuesday, January 10, 1900

Friday, January 13, 1900

Subtask

Direct Push Mobilization

Tuesday, January 10, 1900

Friday, January 13, 1900









Task

Soil Boring Sampling and abandonment

Monday, January 16,1900

Tuesday, January 24,1900

Subtask

Sampling

Monday, January 16, 1900

Monday, January 23, 1900

Subtask

Abandonement

Tuesday, January 24, 1900

Tuesday, January 24, 1900

Subtask

Site Demobilization

Tuesday, January 24, 1900

Tuesday, January 24, 1900









Task

Analysis and Reporting

Tuesday, January 24,1900

Friday, March 9,1900

Subtask

Analyze Samples

Tuesday, January 24, 1900

Tuesday, February 14, 1900

Subtask

Report Results

Tuesday, January 24, 1900

Friday, March 9, 1900









Soil Vapor Monitoing Point Installation

Task

Preparation

Monday, January 3, 2022

Thursday, January 6, 2022

Subtask

Subcontracting

Monday, January 3, 2022

Thursday, January 6, 2022



Laboratory

Monday, January 3, 2022

Thursday, January 6, 2022



Utility Survey/Toning/SVMP Installatiot

Monday, January 3, 2022

Thursday, January 6, 2022

Subtask

Ground Truth Locations

Thursday, January 6, 2022

Thursday, January 6, 2022









Task

Field Work

Thursday, January 6, 2022

Sunday, January 9, 2022

Subtask

Utility Survey/Toning

Thursday, January 6, 2022

Saturday, January 8, 2022

Subtask

Install SVMPs

Thursday, January 6, 2022

Saturday,January 8, 2022

Subtask

Sample SVMPs

Friday, January 7, 2022

Sunday, January 9, 2022









Task

Analysis and Reporting

Sunday, January 9, 2022

ONGOING weekly

Subtask

Analyze Samples

Sunday, January 9, 2022

Weekly

Subtask

Report Results

Sunday, January 9, 2022

Weekly









Geophysical Characterization of Shallow and Deep Subsurface Features



Task

Subcontracting

Monday, January 3, 2022

Thursday, January 6, 2022

Subtask

Laboratory

Monday, January 3, 2022

Thursday, January 6, 2022

Subtask

Utility Survey/Toning

Monday, January 3, 2022

Thursday, January 6, 2022

Subtask

Geophysics Subcontractor

Monday, January 3, 2022

Thursday, January 6, 2022









Task

Site Preparation/Mobilization

Monday, January 10, 2022

Monday, January 31, 2022

Subtask

Utility Survey/Toning (150 locations)

Monday, January 10, 2022

Monday, January 24, 2022

Subtask

Hammer drill (150 locations)

Tuesday, January 11, 2022

Wednesday, January 26, 2022

Subtask

Install Electrodes (150 locations)

Friday, January 14, 2022

Monday, January 31, 2022









-------
Last Updated: 1/2/2022 6:55 PM

Preliminary Schedule

November 20, 2021 Site Characterization

Type

Task Name

Start Date

Finish Date

Task

Conduct Ground Penetrating Radar Surve

Monday, January 31, 2022

Saturday, February 12, 2022

Subtask

Conduct GPR Survey

Monday, January 31, 2022

Friday, February 4, 2022

Subtask

Conduct ER/IP Survey

Saturday, February 5, 2022

Thursday, February 10, 2022

Subtask

Demobilize

Thursday, February 10, 2022

Saturday, February 12, 2022









Task

Analysis and Reporting

Saturday, February 12, 2022

Monday, March 7, 2022

Subtask

Analyze Surveys

Saturday, February 12, 2022

Monday, February 28, 2022

Subtask

Report Results

Monday, February 14, 2022

Monday, March 7, 2022









Near Surface Intrusive Assessment







Preparation

Monday, January 3, 2022

Friday, January 7, 2022

Subtask

Subcontracting

Monday, January 3, 2022

Friday, January 7, 2022



Intrusive Excavatiuon Subcontrator

Monday, January 3, 2022

Friday, January 7, 2022



Utility Survey/Toning

Monday, January 3, 2022

Friday, January 7, 2022

Subtask

Ground Truth Locations

Friday, January 7, 2022

Friday, January 7, 2022









Task

Field Work

Monday, January 10, 2022

Thursday, February 10, 2022

Subtask

Utility Survey/Toning

Monday, January 10, 2022

Friday, January 14, 2022

Subtask

Excavate/cutouts

Monday, January 17, 2022

Friday, January 21, 2022

Subtask

Collect MIS Sample

Wednesday, January 19, 2022

Monday, January 24, 2022

Subtask

Install near surface SVMPs

Wednesday, January 26, 2022

Saturday, January 29, 2022

Subtask

Sample near surface SVMPs

Monday, January 31, 2022

Thursday, February 3, 2022

Subtask

Evaluate Hume Pipe/utility corridor

Friday, January 21, 2022

Thursday, February 3, 2022

Subtask

Replace concrete cut-out/with surface

Thursday, February 3, 2022

Thursday, February 10, 2022









Task

Analysis and Reporting

Thursday, February 10, 2022

Saturday, March 5, 2022

Subtask

Analysis

Thursday, February 10, 2022

Saturday, February 26, 2022

Subtask

Report Results

Saturday, February 12, 2022

Saturday, March 5, 2022

Notes

Schedule is based on Assumption that Navy Work Permit can be obtained by January 10, 2022
Schedule is based on Subcontactor availability

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Appendix B -Analytical Data Package Requirements for Chemical
Analyses

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

This page intentionally left blank

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B	

January 2022

GC-FID Stage 4 Deliverables

Item No.

Deliverable

1

Chain of Custody

2

Sample results with analysis and extraction/preparation dates

3

Summary of MS/MSD/Duplicate recoveries and control limits (listing or link with associated
samples)

4

Summary of LCS/LCSD recoveries and control limits (listing or link with associated
samples)

5

Method blanks (listing or link with associated samples)

6

Summary of surrogate recoveries

7

Summary of initial calibration data (RF and %RSD, or r if applicable)

8

Summary of continuing calibration (%D)

9

Injection logs

10

Extraction/preparation logs

11

Case narrative to discuss anomalies

12

Raw data associated with the summary forms listed above

13

Raw data for item #2 which includes chromatograms, logbooks, quantitation reports, and
spectra

Note: The data deliverable package must have a table of contents and be paginated.

%D

percent difference

%RSD

percent relative standard deviation

GC-FID

gas chromatography-flame ionization detector

MS

matrix spike

MSD

matrix spike duplicate

LCS

laboratory control sample

LCSD

laboratory control sample duplicate

RF

response factor

B-l

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B	

January 2022

GC-MS Stage 4 Deliverables

Item No.

Deliverable

1

Chain of Custody

2

Sample results with analysis and extraction/preparation dates

3

Summary of MS/MSD/Duplicate recoveries and control limits (listing or link with associated
samples)

4

Summary of LCS/LCSD recoveries and control limits (listing or link with associated
samples)

5

Method blanks (listing or link with associated samples)

6

Summary of instrument blanks - metals only (listing or link with associated samples)

7

Summary of surrogate recoveries

8

Summary of initial calibration data (RRF and %RSD, or r if applicable)

9

Summary of continuing calibration (%D and RRF)

10

Summary of internal standards (area response and retention time)

B-2

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B	

January 2022

Item No.

Deliverable

11

Summary of instrument tuning (listing or link with associated samples, must show 12-hour
clock)

12

Injection logs

13

Extraction/preparation logs

14

Case narrative to discuss anomalies

15

Raw data associated with the summary forms listed above

16

Raw data for item #2 which includes chromatograms, logbooks, quantitation reports, and
spectra

Note: The data deliverable package must have a table of contents and be paginated.
GC-MS gas chromatography-mass spectrometry
RRF	relative response factor

General Chemistry Stage 4 Deliverables

Item No.

Deliverable

1

Chain of custody

2

Sample results with analysis and extraction/preparation dates

3

Summary of MS/MSD/Duplicate recoveries and control limits (listing or link with associated
samples)

4

Summary of LCS/LCSD recoveries and control limits (listing or link with associated
samples)

5

Method blanks (listing or link with associated samples)

6

Summary of initial calibration data (correlation coefficient, r)

7

Summary of continuing calibration (%D or % recovery), if applicable

8

Injection logs

9

Extraction/preparation logs, if applicable

10

Case narrative to discuss anomalies

11

Raw data associated with the summary forms listed above

12

Raw data for item #2, which includes logbooks, quantitation reports, and spectra

Note: The data deliverable package must contain a table of contents and be paginated.

B-3

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B	

January 2022

HARD COPY DATA DELIVERABLES COMPACT DISK REQUIREMENTS

The compact disk (CD) shall contain exactly the same information as the hard copy data
deliverables (HDD) including amended and additional pages requested during data review and
validation. Upon completion of data review and validation by AECOM Technical Services, Inc.
or third-party, the laboratory shall be required to provide the CD with the following:

•	The images shall be clear and legible.

•	The images shall be right side up.

•	The images shall be straight.

•	The images shall be in the same order as the HDD.

•	Images may be submitted in PDF, TIFF, or other equivalent imaging format. Files shall be
burned for each page and each CD shall be indexed. The laboratory shall log in samples
based on project number, project name and sample delivery group (also known as batch or
work order).

•	If the images are not clear, legible, right side up, straight or in order, then the laboratory
shall resubmit the CD.

•	The CD label shall contain the following information:

-	Navy contract number

-	Contract task order name and number

-	Sample delivery group number

-	Matrices and methods

-	Date of submittal

B-4

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B	

January 2022

Appendix B.2:

Field Sampling, Analytical, and
Quality Management Reference Tables

•	Table B-l: Location-Specific Sampling Methods/SOP Requirements

•	Table B-2: Analyte List and Reference Limits

•	Table B-3: Preparation and Analytical Requirements for Field and QC Samples

•	Table B-4: Analytical Services

•	Table B-5: Analytical SOP References

•	Table B-6: Laboratory QC Samples

•	Table B-7: Analytical Instrument and Equipment Maintenance, Testing, and Inspection

•	Table B-8: Analytical Instrument Calibration

•	Table B-9: Data Verification and Validation (Steps I and Ila/IIb) Process

B-5

-------
-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B	

January 2022

APPENDIX B.2 - ACRONYMS AND ABBREVIATIONS

%D

percent difference

APPL

Agriculture & Priority Pollutants Laboratories, Inc.

BFB

4-bromofluorobenzene

CA

corrective action

CAS

Chemical Abstracts Service

CCB

continuing calibration blank

CCV

continued calibration verification

D

difference

DFTPP

decafluorotriphenylphosphine

DoD

Department of Defense

DQI

data quality indicator

DQO

data quality objective

EICP

extracted ion current profile

EPA

Environmental Protection Agency, United States

g

gram

GC

gas chromatography

GC-FID

gas chromatography-flame ionization detector

GC-MS

gas chromatography-mass spectrometry

H2SO4

sulfuric acid

HC1

hydrogen chloride

HNO3

nitric acid

ICAL

initial calibration

ICP-AES

inductively coupled plasma-atomic emission spectroscopy

ICV

initial calibration verification

IS

internal standard

L

liter

LCS

laboratory control sample

LDC

Laboratory Data Consultants

LOD

limit of detection

LOQ

limit of quantitation

MB

method blank

mg/kg

milligram per kilogram

mL

milliliter

MPC

measurement performance criteria

MS

matrix spike

MSD

matrix spike duplicate

N/A

not applicable

NaHS04

sodium bisulfate

NAPL

non-aqueous-phase liquid

NIST

National Institute of Standards and Technology

oz

ounce

PFTBA

perfluorotributylamine

QA

quality assurance

QC

quality control

QSM

Quality Systems Manual

RPD

relative percent difference

B-7

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B	

January 2022

RRT

relative retention time

RSD

relative standard deviation

RT

retention time

SOP

standard operating procedure

TBD

to be determined

B-8

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Table B-l: Location-Specific Sampling Methods/SOP Requirements

Sampling Location/ID
Number

Matrix

Depth
(ft bgs)

Analytical Group

Number of Samples

Sampling SOP Reference

LFSB01, LFSB02,
LFSB03, LFSB04 plus
potential 10 additional
step-out borings

Unconsolidated Material

approx.
200

Chemical Analyses:
VOCs, PAHs, TPH-d

At each soil boring:
1 composite subsurface
soil sample of the entire
petroleum-impacted soil
core;

1 discrete subsurface soil
sample at the total depth
of the boring;

1 duplicate per 10
subsurface soil samples;
1 MS/MSD pair per 20
subsurface soil samples
1 trip blank per cooler
containing VOCs.

Procedure I-B-l Soil
Sampling

HTSB01, HTSB02,
HTSB03, HTSB04 plus
potential 10 additional
step-out borings

Unconsolidated Material

approx.
200

Chemical Analyses:
VOCs, PAHs, TPH-d

At each soil boring:
1 composite subsurface
soil sample of the entire
petroleum-impacted soil
core;

1 discrete subsurface soil
sample at the total depth
of the boring;

1 duplicate per 10
subsurface soil samples;
1 MS/MSD pair per 20
subsurface soil samples
1 trip blank per cooler
containing VOCs.

Procedure I-B-l Soil
Sampling

Notes: Procedures are from the Project Procedures Manual (DON 2015).

Actual number of unconsolidated material samples will be dependent on field observations during coring.

Volumes for field duplicate, and MS/MSD samples will only be collected if sufficient unconsolidated material is present at each sampling interval. If limited
volume is present, collecting volume for VOCs, PAHs, and TPH will take priority.

B-9

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

Appendix B

One trip blank will be collected during each unconsolidated material sampling event.

TPH with silica gel cleanup will only be analyzed for sample with detections of TPH-d and TPH-o from the non-silica gel cleaned extract.

B-10

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

Appendix B

Table B-2: Location-Specific Sampling Methods/SOP Requirements

B-ll

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Matrix Unconsolidated Material











Laboratory-Specific Limits (mg/kg)

Analyte

CAS Number

Screening Criterion

a

(mg/kg)

Project LOQ Goal
(mg/kg)

Project LOD Goal
(mg/kg)

LOQ

LOD

DL

TPH

TPH-g (C5-C11)

-3547

100

33

10

TBD

TBD

TBD

TPH-d (C10-C24)

-3527

220

73

22

TBD

TBD

TBD

VOCs

Benzene

71-43-2

0.30

0.10

0.030

TBD

TBD

TBD

Ethylbenzene

100-41-4

3.7

1.2

0.37

TBD

TBD

TBD

Toluene

108-88-3

3.2

1.1

0.32

TBD

TBD

TBD

Total Xylenes

1330-20-7

2.1

0.70

0.21

TBD

TBD

TBD

PAHs

1 -Methy lnaphthalene

90-12-0

4.2

1.4

0.42

TBD

TBD

TBD

2-Methylnaphthalene

91-57-6

4.1

1.4

0.41

TBD

TBD

TBD

Naphthalene

91-20-3

4.4

1.5

0.44

TBD

TBD

TBD

Notes:

mg/kg milligrams per kilogram
a DOH Tier 1 EALs (Summer 2016, updated January 2017),

B-12

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

Appendix B

Table B-3: Preparation and Analytical Requirements for Field and QC Samples

Matrix

Analytical Group

Preparation Reference/Method SOP
Analytical Reference/Method SOP

Containers

Sample
Volume

Preservation
Requirement

Maximum Holding
Time

(preparation/analysis)

Unconsolidated
Material

TPH-g, VOCs

Preparation Method: EPA 5035C
Preparation SOP: ANA8260
Analysis Method: EPA 8260C
Analysis SOP: ANA8260

2 x 10mL water-
preserved; 1 x 5mL
methanol-preserved;
Teflon-lined septum
caps

40 mL

Cool to <6°C

7 days (water-
preserved); 14 days
(methanol-preserved)



TPH-d, TPH-o

Preparation Method: EPA 3550C
Preparation SOP: SON004
Analysis Method: EPA 8015C
Analysis SOP: ANA8015

1 x 8-oz glass jar,
Teflon-lined lid

30 g

Cool to <6°C

Samples extracted
within 14 days and
analyzed within 40
days following
extraction.



TPH-d, TPH-o with
Silica Gel Cleanup

Preparation Method: EPA 3550C/EPA 3630
Preparation SOP: SON004/CLN004
Analysis Method: EPA 8015C
Analysis SOP: ANA8015



30 g

Cool to <6°C

Samples extracted
within 14 days and
analyzed within 40
days following
extraction.



PAHs

Preparation Method: EPA 3550C
Preparation SOP: SON009
Analysis Method: EPA 8270D SIM
Analysis SOP: ANA8270SIM



30 g

Cool to <6°C

Samples extracted
within 14 days and
analyzed within 40
days following
extraction.

Notes:
g

gram

H2SO4

sulfuric acid

HC1

hydrogen chloride

L

liter

mL

milliliter

NaHS04

sodium bisulfate

oz

ounce

B-13

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Table B-4: Analytical Services

Matrix

Analytical Group

Sampling Locations/
ID Numbers

Analytical SOP

Data Package
Turnaround Time

Laboratory/Organization
(name and address)

Unconsolidated
Material

VOCs (BTEX)

TPH-g, TPH-d,

PAHs (1-methylnaphthalene,
2-methylnaphthalene, naphthalene)

LFSB01, LFSB02,
LFSB03, LFSB04 plus
potential 10 additional
step-out borings;
HTSB01, HTSB02,
HTSB03, HTSB04
plus potential 10
additional step-out
borings

ANA8260,
ANA8015,
ANA8270SIM

14 days after
samples are
received at
laboratory

TBD

a Laboratory meets DOD ELAP or AASHTO accreditation requirements, as applicable, to support project needs.

B-14

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Table B-5: Analytical SOP References

Laboratory: TBD

Point of Contact: TBD

Point of Contact Phone Number: TBD

Lab SOP Number

Title, Revision Date, and/or Number

Definitive or
Screening Data

Matrix and Analytical
Group

Instrument

Variance to QSM
(Y es/No)

Modified for Project
Work? (Yes/No)

Preparatory
Methods

ANA8260

Analysis Of Water/Soil/Sludge By
EPA Method 8260, Rev 22, 4/4/18

Definitive

VOCs, TPH-g
(Unconsolidated
Material, Water)

Preparation

No

No

SONOOl

Sonication Extraction of Soil, Sludge,
and Solid (EPA Method 3550C), Rev
5, 0907/18

Definitive

TPH-d, TPH-o, PAHs

(Unconsolidated

Material)

Preparation

No

No

CLN004

3630C Silica Gel Cleanup, Rev 2,
12/22/16

Definitive

TPH-d, TPH-o
Silica Gel Cleanup
(Unconsolidated
Material)

Preparation

No

No

Analytical
Methods

ANA8260

Analysis Of Water/Soil/Sludge By
EPA Method 8260, Rev 22, 4/4/18

Definitive

VOCs, TPH-g
(Unconsolidated
Material, Water)

GC-MS

No

No

ANA8015

Determination Of Total Extractable
Petroleum Hydrocarbons (TPH) In
Water, Sludges And Soils By GC-
FID, Rev 11,4/4/18

Definitive

TPH-d, TPH-o
(Unconsolidated
Material, Water)

GC-FID

No

No

ANA8270SIM

PAH By SIM By EPA Method
8270, Rev 8, 12/26/17

Definitive

PAHs

(Unconsolidated
Material, Water)

GC-MS

No

No

Note: The laboratory SOPs listed in the table are the most current revisions at the time of publication of this MW1WP Addendum 03. The Navy consultant will
review the laboratory SOPs immediately prior to sample submittal to ensure that the laboratory uses SOPs that are in compliance with the DoD QSM annual
review requirement.

GC-FID gas chromatography-flame ionization detector

B-15

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

Appendix B

GC-MS gas chromatography-mass spectrometry

ICP-AES inductively coupled plasma-atomic emission spectroscopy

B-16

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Table B-6: Laboratory QC Samples

Matrix

Analytical Group

Analytical Method/SOP Reference
Analytical Organization

for Chemistry Analyses

Unconsolidated Material
VOCs, TPH-g

Analytical Method: SW-846 8260C
Preparation Method: EPA 5035A, EPA 5030B
Laboratory SOPs: ANA8260

TBD

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOD

determination
and verification

At initial set-up and
verified quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOD must
be verified on each.

The apparent signal to
noise ratio must be at
least 3 and the results
must meet all method
requirements for analyte
identification.

If the LOD verification fails,
the laboratory must:

1)	Repeat the detection limit
determination and LOD
verification at a higher
concentration; or

2)	Perform and pass two
consecutive LOD verifications
at a higher concentration. The
LOD is set at the higher
concentration.

Analyst
Lab QA
Officer
Project
Chemist

Bias/

Representative-
ness

QC acceptance criteria
as specified by Lab SOP
ANA8260.

B-17

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOQ

establishment
and verification

At initial setup:

1)	Verify LOQ; and

2)	Determine precision
and bias at the LOQ.
Subsequently, verify
LOQ quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOQ must
be verified on each.

1)	The LOQ and
associated precision and
bias must meet client
requirements and must
be reported; or

2)	In the absence of
client requirements,
must meet control limits
of the LCS.

3)	If the method is
modified, precision and
bias at the new LOQ
must be demonstrated
and reported. See
Volume 1, Module 4,
Section 1.5.2 of the
DoD QSM5.4 (DoD
and DOE 2021).

If the LOQ verification fails,
the laboratory must either
establish a higher LOQ or
modify method to meet the
client-required precision and
bias.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

QC acceptance criteria
as specified by Lab SOP
ANA8260 and at least
as stringent as specified
by DoD QSM5.4 (DoD
and DOE 2021).

Tune check

Prior to the ICAL and
prior to each 12-hour
period of sample
analysis.

Specific ion abundance
criteria of BFB or
DFTPP from method.

Retune instrument and verify.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No samples may be
analyzed without a
passing tune.

B-18

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

ccv

Before sample analysis,
after every 10 field
samples, after every 12
hours of analysis time,
and at the end of the
analysis sequence.

All reported analytes
and surrogates within
established RT
windows. All reported
analytes and surrogates
within ±20% of true
value. All reported
analytes and surrogates
within ±50% for the end
of the analytical batch
CCV.

Immediately analyze two
additional consecutive CCVs.
If both pass, samples may be
reported without reanalysis. If
either fails, take corrective
action(s) and re-calibrate; then
reanalyze all affected samples
since the last acceptable CCV.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

Results may not be
reported without a valid
CCV. If reanalysis
cannot be performed,
data must be qualified
and explained in the
case narrative. If the
specific version of a
method requires
additional evaluation
(e.g., average response
factors) these additional
requirements must also
be met.

MB

Each time analytical
batch.

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher. For
common lab
contaminants, no
analytes detected
>LOQ.

Correct problem. If required,
re-prep and reanalyze MB and
all samples processed with the
contaminated blank.

Analyst
Lab QA
Officer
Project
Chemist

Bias

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher.
For common laboratory
contaminants, no
analytes detected
>LOQ.

LCS

One per batch of at most
20 samples analyzed of
similar matrix per
analytical method.

Per DoD QSM
Appendix C Limits,
Method SW-846 8260C
and Lab SOP
ANA8260.

Correct problem. If required,
re-prep and reanalyze the LCS
and all samples processed in
the associated preparatory
batch for the failed analytes.
Results may not be reported
without a valid LCS.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

B-19

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

MS/MSD pair

One per analytical
method for each batch of
at most 20 samples.

Per DoD QSM
Appendix C Limits,
Method SW-846 8260C
and Lab SOP
ANA8260.

MSD or Matrix
Duplicate: RPD of all
analytes <20%.

Examine the PQOs. Notify
Lab QA officer and project
chemist about additional
measures to be taken.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

For matrix evaluation,
use QC acceptance
criteria at least as
stringent as specified by
DoD QSM 5.4 (DoD
and DOE 2021).

Internal

standards

verification

Every field sample,
standard, and QC
sample.

Retention time ±10
seconds from retention
time of the midpoint
standard in the ICAL;
EICP area within -50%
to+100% of ICAL
midpoint standard.

Inspect mass spectrometer and
GC for malfunctions.
Reanalysis of samples
analyzed while system was
malfunctioning is mandatory.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

Laboratory in-house
method manual to be
followed for acceptance
criteria.

Surrogate spike

All field and QC
samples.

Per DoD QSM
Appendix C Limits,
Method SW-846 8260C
and Lab SOP
ANA8260.

For QC and field samples,
correct problem then re-prep
and reanalyze all failed
samples for failed surrogates
in the associated preparatory
batch, if sufficient sample
material is available. If
obvious chromatographic
interference with surrogate is
present, reanalysis may not be
necessary.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

Trip blank

1 per cooler.

Target analytes <1/2
LOQ.

Reanalyze for confirmation
through a second analysis of
the trip blank. Examine the
PQOs.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/Bias,
Representative -
ness/Contaminat
ion

Target analytes <1/2
LOQ.

B-20

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Matrix	Unconsolidated Material

Analytical Group	TPH-d, TPH-o with and without Silica Gel Cleanup

Analytical Method/SOP Reference	Analytical Method: EPA Method 8015C

Preparation Method: EPA 3550C/3630C, EPA 3510C/3630C
Laboratory SOPs: SON001, CLN004, SEP11, ANA8015

Analytical Organization	TBD

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement

Performance

Criteria

LOD

determination
and verification

At initial set-up and
verified quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOD must
be verified on each.

The apparent signal to
noise ratio must be at
least 3 and the results
must meet all method
requirements for analyte
identification.

If the LOD verification fails,
the laboratory must:

1)	Repeat the detection limit
determination and LOD
verification at a higher
concentration; or

2)	Perform and pass two
consecutive LOD verifications
at a higher concentration. The
LOD is set at the higher
concentration.

Analyst
Lab QA
Officer
Project
Chemist

Bias/

Representative-
ness

QC acceptance criteria
as specified by Lab SOP
ANA8015.

B-21

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement

Performance

Criteria

LOQ

establishment
and verification

At initial setup:

1)	Verify LOQ; and

2)	Determine precision
and bias at the LOQ.
Subsequently, verify
LOQ quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOQ must
be verified on each.

1)	The LOQ and
associated precision and
bias must meet client
requirements and must
be reported; or

2)	In the absence of
client requirements,
must meet control limits
of the LCS.

3)	If the method is
modified, precision and
bias at the new LOQ
must be demonstrated
and reported. See
Volume 1, Module 4,
Section 1.5.2 of the DoD
QSM5.4 (DoD and
DOE 2021).

If the LOQ verification fails,
the laboratory must either
establish a higher LOQ or
modify method to meet the
client-required precision and
bias.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

QC acceptance criteria
as specified by Lab SOP
ANA8015, and at least
as stringent as specified
by DoD QSM5.4 (DoD
and DOE 2021).

ccv

Before sample analysis,
after every 10 field
samples, and at the end
of the analysis sequence.

All reported analytes
and surrogates within
established RT
windows. All reported
analytes and surrogates
within ±20% of true
value.

Immediately analyze two
additional consecutive CCVs.
If both pass, samples may be
reported without reanalysis. If
either fails, take corrective
action(s) and re-calibrate; then
reanalyze all affected samples
since the last acceptable CCV.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

Results may not be
reported without a valid
CCV. If reanalysis
cannot be performed,
data must be qualified
and explained in the
case narrative.

B-22

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement

Performance

Criteria

MB

Each time samples are
extracted and one per
matrix per analytical
method for each batch of
at most 20 samples.

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher. For
common lab
contaminants, no
analytes detected >LOQ.

Correct problem. If required,
re-prep and reanalyze MB and
all samples processed with the
contaminated blank.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher.
For common laboratory
contaminants, no
analytes detected
>LOQ.

LCS

One per batch of at most
20 samples analyzed of
similar matrix per
analytical method.

Per DoD QSM
Appendix C Limits,
Method 8015C and Lab
SOP ANA8015.

Correct problem. If required,
re-prep and reanalyze the LCS
and all samples processed in
the associated preparatory
batch for the failed analytes.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

Internal

standards

verification

Every field sample,
standard, and QC
sample.

Retention time ±30
seconds from retention
time of the midpoint
standard in the ICAL;
EICP area within -50%
to+100% of ICAL
midpoint standard.

Inspect mass spectrometer and
GC for malfunctions.
Reanalysis of samples
analyzed while system was
malfunctioning is mandatory.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

Laboratory in-house
method manual to be
followed for acceptance
criteria.

B-23

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement

Performance

Criteria

Surrogate spike

All field and QC
samples.

Per DoD QSM
Appendix C Limits,
Method 8015C and Lab
SOP ANA8015.

For QC and field samples,
correct problem then re-prep
and reanalyze all failed
samples for failed surrogates
in the associated preparatory
batch, if sufficient sample
material is available. If
obvious chromatographic
interference with surrogate is
present, reanalysis may not be
necessary.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

Surrogate spike
for silica gel
cleanup
procedure

All field and QC
samples.

Acceptable recovery
range of 0 to 1% of
spiked amount of polar
hydrocarbon surrogate.

For QC and field samples, if
sufficient sample extract is
available, re-run extracts
through silica gel cleanup
procedure and reanalyze all
failed samples for failed
surrogates in the associated
preparatory batch. Otherwise,
re-extract samples and re-run
silica gel cleanup on re-extract
prior to re-analysis, if
sufficient sample material is
available.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

Polar hydrocarbon
surrogate recovered at
<1% of spiked amount.

MS/MSD pair

One per analytical
method for each batch of
at most 20 samples.

Per DoD QSM
Appendix C Limits,
Method 8015C and Lab
SOP ANA8015.
MSD or Matrix
Duplicate: RPD of all
analytes <30%.

Examine the PQOs. Notify
Lab QA officer and project
chemist about additional
measures to be taken.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

For matrix evaluation,
use QC acceptance
criteria at least as
stringent as specified by
DoD QSM 5.4 (DoD
and DOE 2021).

B-24

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Matrix	Unconsolidated Material

Analytical Group	PAHs

Analytical Method/SOP Reference	Analytical Method: EPA Method 8270D SIM

Preparation Method: EPA3550C, EPA3510C
Laboratory SOPs: SON001, SEP004, ANA8270SIM

Analytical Organization	TBD

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOD

determination
and verification

At initial set-up and
verified quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOD must
be verified on each.

The apparent signal to
noise ratio must be at
least 3 and the results
must meet all method
requirements for analyte
identification.

If the LOD verification fails,
the laboratory must:

1)	Repeat the detection limit
determination and LOD
verification at a higher
concentration; or

2)	Perform and pass two
consecutive LOD verifications
at a higher concentration. The
LOD is set at the higher
concentration.

Analyst
Lab QA
Officer
Project
Chemist

Bias/

Representative-
ness

QC acceptance criteria
as specified by Lab SOP
ANA8270SIM.

B-25

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOQ

establishment
and verification

At initial setup:

1)	Verify LOQ; and

2)	Determine precision
and bias at the LOQ.
Subsequently, verify
LOQ quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOQ must
be verified on each.

1)	The LOQ and
associated precision and
bias must meet client
requirements and must
be reported; or

2)	In the absence of
client requirements,
must meet control limits
of the LCS.

3)	If the method is
modified, precision and
bias at the new LOQ
must be demonstrated
and reported. See
Volume 1, Module 4,
Section 1.5.2 of the DoD
QSM5.4 (DoD and
DOE 2021).

If the LOQ verification fails,
the laboratory must either
establish a higher LOQ or
modify method to meet the
client-required precision and
bias.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

QC acceptance criteria
as specified by Lab SOP
ANA8270SIM, and at
least as stringent as
specified by DoD
QSM5.4 (DoD and
DOE 2021).

Performance
check

Before ICAL and sample
analysis, and at the
beginning of each 12-
hour shift.

Degradation of DDT
must be <20%.
Benzidine and
pentachlorophenol will
be present at their
normal responses and
will not exceed a tailing
factor of 2.

Correct problem, then repeat
performance checks.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

Degradation of DDT
must be <20%; and
benzidine and
pentachlorophenol must
be present at normal
responses and tailing
factor is <2. No samples
must be analyzed until
performance check is
within criteria.

B-26

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

Tune Check

Prior to the ICAL and
prior to each 12-hour
period of sample
analysis.

Specific ion abundance
criteria of BFB or
DFTPP from method.

Retune instrument and verify

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No samples may be
analyzed without a
passing tune.

ccv

Before sample analysis,
after every 10 field
samples, after every 12
hours of analysis time,
and at the end of the
analysis sequence.

All reported analytes
and surrogates within
established RT
windows. All reported
analytes and surrogates
within ±20% of true
value.

Immediately analyze two
additional consecutive CCVs.
If both pass, samples may be
reported without reanalysis. If
either fails, take corrective
action(s) and re-calibrate; then
reanalyze all affected samples
since the last acceptable CCV.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

Results may not be
reported without a valid
CCV. If reanalysis
cannot be performed,
data must be qualified
and explained in the
case narrative.

MB

Each time samples are
extracted and one per
matrix per analytical
method for each batch of
at most 20 samples.

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher. For
common lab
contaminants, no
analytes detected >LOQ.

Correct problem. If required,
re-prep and reanalyze MB and
all samples processed with the
contaminated blank.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher.
For common laboratory
contaminants, no
analytes detected
>LOQ.

LCS

One per batch of at most
20 samples analyzed of
similar matrix per
analytical method.

Per DoD QSM
Appendix C Limits,
Method 8270D SIM and
Lab SOP
ANA8270SIM.

Correct problem. If required,
re-prep and reanalyze the LCS
and all samples processed in
the associated preparatory
batch for the failed analytes.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

B-27

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

Internal

standards

verification

Every field sample,
standard, and QC
sample.

Retention time ±10
seconds from retention
time of the midpoint
standard in the ICAL;
EICP area within -50%
to+100% of ICAL
midpoint standard.

Inspect mass spectrometer and
GC for malfunctions.
Reanalysis of samples
analyzed while system was
malfunctioning is mandatory.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

Laboratory in-house
method manual to be
followed for acceptance
criteria.

Surrogate spike

All field and QC
samples.

Per DoD QSM
Appendix C Limits,
Method 8270D SIM and
Lab SOP
ANA8270SIM.

For QC and field samples,
correct problem then re-prep
and reanalyze all failed
samples for failed surrogates
in the associated preparatory
batch, if sufficient sample
material is available. If
obvious chromatographic
interference with surrogate is
present, reanalysis may not be
necessary.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

MS/MSD pair

One per analytical
method for each batch of
at most 20 samples.

Per DoD QSM
Appendix C Limits,
Method 8270D SIM and
Lab SOP
ANA8270SIM.

MSD or Matrix
Duplicate: RPD of all
analytes <20%.

Examine the PQOs. Notify
Lab QA Officer and project
chemist about additional
measures to be taken.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

For matrix evaluation,
use QC acceptance
criteria at least as
stringent as specified by
DoD QSM 5.4 (DoD
and DOE 2021).

B-28

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOD

determination
and verification

At initial set-up and
verified quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOD must
be verified on each.

The apparent signal to
noise ratio must be at
least 3 and the results
must meet all method
requirements for analyte
identification.

If the LOD verification fails,
the laboratory must:

1)	Repeat the detection limit
determination and LOD
verification at a higher
concentration; or

2)	Perform and pass two
consecutive LOD verifications
at a higher concentration. The
LOD is set at the higher
concentration.

Analyst
Lab QA
Officer
Project
Chemist

Bias/

Representative-
ness

QC acceptance criteria
as specified by Lab SOP
TBD.

LOQ

establishment
and verification

At initial setup:

1)	Verify LOQ; and

2)	Determine precision
and bias at the LOQ.
Subsequently, verify
LOQ quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOQ must
be verified on each.

1)	The LOQ and
associated precision and
bias must meet client
requirements and must
be reported; or

2)	In the absence of
client requirements,
must meet control limits
of the LCS.

3)	If the method is
modified, precision and
bias at the new LOQ
must be demonstrated
and reported. See
Volume 1, Module 4,
Section 1.5.2 of the DoD
QSM5.4 (DoD and
DOE 2021).

If the LOQ verification fails,
the laboratory must either
establish a higher LOQ or
modify method to meet the
client-required precision and
bias.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

QC acceptance criteria
as specified by Lab SOP
TBD, and at least as
stringent as specified by
DoD QSM5.4 (DoD
and DOE 2021).

B-29

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

MB

Each time samples are
extracted and one per
matrix per analytical
method for each batch of
at most 20 samples.

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher. For
common lab
contaminants, no
analytes detected >LOQ.

Correct problem. If required,
re-prep and reanalyze MB and
all samples processed with the
contaminated blank.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher.
For common laboratory
contaminants, no
analytes detected
>LOQ.

LCS

One per batch of at most
20 samples analyzed of
similar matrix per
analytical method.

Per DoD QSM
Appendix C Limits,
Method TBD and Lab
SOP TBD.

Correct problem. If required,
re-prep and reanalyze the LCS
and all samples processed in
the associated preparatory
batch for the failed analytes.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

Note: No laboratory QC samples are generated for geotechnical and petrographic analyses.

B-30

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Table B-7: Analytical Instrument and Equipment Maintenance, Testing, and Inspection

Instrument/
Equipment

Maintenance
Activity

Testing
Activity

Inspection
Activity

Frequency

Acceptance
Criteria

Corrective
Action

Responsible Person

SOP Reference a

GC-FID and
GC-MS

Change gas
purifier.

N/A

Visually inspect
if traps are
changing color.

Every 6-12
months

No moisture

Replace

indicating traps.

Analyst or certified

instrument

technician

ANA8015,

ANA8270SIM,

ANA8270



Change

syringes/syringe
needles.

N/A

Visually inspect
for wear or
damage.

Every 3 months

N/A

Replace syringe
if dirt is
noticeable in
the syringe.

Analyst or certified

instrument

technician





Change inlet liner,
liner O-rings, and
inlet septum.

N/A

Visually inspect
for dirt or
deterioration.

Weekly for
liner

Monthly for 0-
rings
Daily for
septum

N/A

Replace and
check often.

Analyst or certified

instrument

technician





Change front-end
column.

N/A

Check peak
tailing,
decreased
sensitivity,
retention time
changes, etc.

Weekly,
monthly, or
when needed

N/A

Remove 1/2 to
1 meter from
the front of the
column when
experiencing
problems.

Analyst or certified

instrument

technician





Clean injector
ports.

N/A

N/A

As needed

N/A

N/A

Analyst





Replace trap on

purge-and-trap

systems.

N/A

N/A

Bi-monthly or
as needed

N/A

N/A

Analyst





Replace columns.

N/A

N/A

If

chromatograms
indicate
possible
contamination

N/A

N/A

Analyst



B-31

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Instrument/
Equipment

Maintenance
Activity

Testing
Activity

Inspection
Activity

Frequency

Acceptance
Criteria

Corrective
Action

Responsible Person

SOP Reference a

GC-FID

Replace detector
jets.

N/A

N/A

As needed

N/A

N/A

Analyst

ANA8015



Replace

hydrocarbon traps
and oxygen traps
on helium and
hydrogen gas lines.

N/A

N/A

Every 4-6
months

N/A

N/A

Analyst





Replace chemical
trap.

N/A

N/A

Yearly or as
needed

N/A

N/A

Analyst





Replace converter
tube in gas purifier
system.

N/A

N/A

Yearly or as
needed

N/A

N/A

Analyst



B-32

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Instrument/
Equipment

Maintenance
Activity

Testing
Activity

Inspection
Activity

Frequency

Acceptance
Criteria

Corrective
Action

Responsible Person

SOP Reference a

GC-MS

Change tune MSD,
check the
calibration vial,
and replace the
foreline pump oil.

N/A

Visually inspect
and monitor the
fluid becoming
discolored.

As needed or
every 6 months

In accordance
with

manufacturer's
recommendatio
n or lab SOP

Keep plenty of
PFTBA; refill
the vial and
check the fluid;
change when
the fluid
becomes
discolored.

Analyst or certified

instrument

technician

ANA8270SIM,
ANA8270



Run tuning
program to
determine if source
is functioning
properly.

N/A

N/A

Daily

N/A

Cool system,
vent,

disassemble,
and clean.

Analyst

ANA8270SIM,
ANA8270



N/A

Tune

instrument.

N/A

Daily or every
12 hours

Per method

Liner and septa
are replaced;
tune file used is
manually
adjusted.

Analyst





Vacuum rough
pump oil level is
checked.

N/A

N/A

Every 4-6
weeks

N/A

Add oil if
needed.

Analyst





Replace/refill
carrier gas line
oxygen and
moisture traps.

N/A

N/A

Yearly or as
needed

N/A

N/A

Analyst



Water Bath
(Precision
Microprocess
or controlled)

Check instrument
connections, water
level, and
thermometer.

Measure water
temperature
against a
calibrated
thermometer.

Visually inspect
for wear or
damage and
indicator from
computer
controls.

Daily and
annual
maintenance
from

manufacturer

Refer to
manufacturer's
recommendatio
n

Return to
manufacturer
for recalibration
or call for
maintenance
service.

Analyst or certified

instrument

technician

INS001

B-33

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01	January 2022

Appendix B

Instrument/
Equipment

Maintenance
Activity

Testing
Activity

Inspection
Activity

Frequency

Acceptance
Criteria

Corrective
Action

Responsible Person

SOP Reference a

Drying Oven

Thermometer
indicator.

Measure oven
temperature
against a
calibrated
thermometer.

Visually inspect
for wear or
damage and
indicator from
computer
controls.

Daily and
annual
maintenance
from

manufacturer

Refer to
manufacturer's
recommendatio
n

Return to
manufacturer
for recalibration
or call for
maintenance
service.

Analyst or certified

instrument

technician

INO003

Analytical
Balance

Check digital LCD
display and ensure
a flat base for the
Instrument.

Calibrate
against
verified
(NIST) mass.

Visually inspect
for wear or
damage and
indicator from
computer
controls.

Daily and
annual
maintenance
from

manufacturer

Refer to
manufacturer's
recommendatio
n

Return to
manufacturer
for recalibration
or call for
maintenance
service.

Analyst or certified

instrument

technician

INO011

pH Meter

Check LCD
display and pH
probe.

3 point
calibration
using known
standards.

Visually inspect
for wear or
damage and
indicator from
computer
controls.

Daily and
annual
maintenance
from

manufacturer

±0.05 units

Return to
manufacturer
for recalibration
or call for
maintenance
service.

Analyst or certified
manufacture
instrument
technician

INO038

Note: No instrument and equipment maintenance, testing, and inspection criteria for geotechnical and petrographic analyses.
N/A	not applicable

NIST National Institute of Standards and Technology
PFTBA perfluorotributylamine
a See Analytical SOP References table (Table F-5).

B-34

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Table B-8: Analytical Instrument Calibration

Instrument

Calibration Procedure

Frequency of
Calibration

Acceptance Criteria

Corrective Action

Person Responsible
for Corrective Action

SOP Reference

a

GC-MS
EPA Methods
8260C, 8720D
SIM

Tuning

Prior to ICAL and at
the beginning of each
12-hour period

Refer to method for
specific ion criteria.

Retune instrument and
verify. Rerun affected
samples.

Lab Manager/Analyst
or certified instrument
technician

ANA8270SIM,
ANA8270



Breakdown check (DDT-Method
8270 only)

At the beginning of
each 12-hour period,
prior to analysis of
samples

Degradation <20% for
DDT. Benzidine and
pentachlorophenol
should be present at
their normal responses
and should not exceed a
tailing factor of 2.

Correct problem, then
repeat breakdown
checks.

Lab Manager/Analyst
or certified instrument
technician





Minimum 5-point ICAL
for linear calibration
Minimum 6-point ICAL
for quadratic calibration

Prior to sample
analysis

RSD for each analyte
<15% or least square
regression >0.995. Non-
linear least squares
regression (quadratic)
for each analyte <0.995.

Correct problem then
repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician





Second source
calibration verification

After ICAL

All analytes within
±20% of expected value.

Correct problem and
verify second source
standard; rerun second
source verification. If
fails, correct problem
and repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician





RT window position for
each analyte and
surrogate

Once per ICAL

Position will be set
using the midpoint
standard for the ICAL.

N/A

Lab Manager/Analyst
or certified instrument
technician



B-35

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Instrument

Calibration Procedure

Frequency of
Calibration

Acceptance Criteria

Corrective Action

Person Responsible
for Corrective Action

SOP Reference

a



RRT

With each sample

RRT of each target
analyte in each
calibration standard
within ±0.06 RRT units
of ICAL.

Correct problem, then
reanalyze all samples
analyzed since the last
RT check. If fails, then
rerun ICAL and
samples.

Lab Manager/Analyst
or certified instrument
technician





CCV

Daily, before sample
analysis, unless ICAL
performed same day
and after every
10 samples and at the
end of the analysis
sequence

All analytes within
±20% of expected value
(%D).

All reported analytes
and surrogates within
±50% for end of
analytical batch CCV.

Immediately analyze
two additional
consecutive CCVs. If
both pass, samples may
be reported without
reanalysis. If either fails,
take corrective action(s)
and re-calibrate; then
reanalyze all affected
samples since the last
acceptable CCV.

Lab Manager/Analyst
or certified instrument
technician





IS

Each CCV and sample

RT ±10 seconds from
RT of the ICAL mid-
point standard. EICP
area within -50% to
+100% of area from IS
in ICAL mid-point
standard.

Inspect mass
spectrometer and GC for
malfunctions.

Reanalysis of samples
analyzed during failure
is mandatory.

Lab Manager/Analyst
or certified instrument
technician



B-36

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Instrument

Calibration Procedure

Frequency of
Calibration

Acceptance Criteria

Corrective Action

Person Responsible
for Corrective Action

SOP Reference

a

GC-FID
EPA Method
8015C

Minimum 5-point ICAL
for linear calibration
Minimum 6-point ICAL
for quadratic calibration

Prior to sample
analysis

RSD for each analyte
<20% or least square
regression >0.995. Non-
linear least squares
regression (quadratic)
for each analyte <0.995.

Correct problem then
repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician

ANA8015



Second source
calibration verification

Once after each ICAL

Analytes within ±20%
of expected value (initial
source), and within
established RT
windows.

Correct problem and
verify second source
standard. Rerun second
source verification. If
fails, correct problem
and repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician





RT window width

At method set-up and
after major
maintenance

RT width is ±3 times
standard deviation for
each analyte RT from
72-hour study. For TPH-
d: calculate RT based on
C12 and C25 alkanes.

N/A

Lab Manager/Analyst
or certified instrument
technician





Establishment and
verification of the RT
window for each analyte
and surrogate

Once per ICAL and at
the beginning of the
analytical shift for
establishment of RT;
and with each CCV for
verification of RT

Using the midpoint
standard or the CCV at
the beginning of the
analytical shift for RT
establishment; and
analyte must fall within
established window
during RT verification.

N/A

Lab Manager/Analyst
or certified instrument
technician





Run second source
calibration verification
(ICY)

ICV: Daily, before
sample analysis, unless
ICAL performed same
day

All analytes within
±20% of expected value
(%D).

Correct problem and
rerun ICV. If fails,
repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician



B-37

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Instrument

Calibration Procedure

Frequency of
Calibration

Acceptance Criteria

Corrective Action

Person Responsible
for Corrective Action

SOP Reference

a



ccv

Daily, before sample
analysis, unless ICAL
performed same day
and after every
10 samples and at the
end of the analysis
sequence

All analytes within
±20% of expected value
(%D).

Immediately analyze
two additional
consecutive CCVs. If
both pass, samples may
be reported without
reanalysis. If either fails,
take corrective action(s)
and re-calibrate; then
reanalyze all affected
samples since the last
acceptable CCV.

Lab Manager/Analyst
or certified instrument
technician



Water Bath

Measure water
temperature against a
calibrated thermometer

Annually

In accordance with unit
model and
manufacturer's
recommendation or
laboratory SOP.

Terminate analysis,
recalibrate, and verify
before sample analysis.

Lab Manager/Analyst
or certified instrument
technician

INS001

Drying Oven

Measure oven
temperature against a
calibrated thermometer

Annually

In accordance with unit
model and
manufacturer's
recommendation or
laboratory SOP.

Terminate analysis,
recalibrate, and verify
before sample analysis.

Lab Manager/Analyst
or certified instrument
technician

INO003

Analytical
Balance

Calibrate against
verified (NIST) mass

Daily or prior to
analyzing samples

In accordance with unit
model and
manufacturer's
recommendation or
laboratory SOP.

Terminate analysis,
recalibrate, and verify
before sample analysis.

Lab Manager/Analyst
or certified instrument
technician

INO011

pH Meter

Run a minimum 3-point
calibration; run CCV

Daily or prior to
analyzing samples; one
CCV for every
10 samples

±0.05 unit.

Terminate analysis,
recalibrate, and verify
before sample analysis.

Lab Manager/Analyst
or certified instrument
technician

INO038

Note: No instrument calibration procedures for geotechnical and petrographic analyses.

B-38

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

%D

percent difference

CA

corrective action

CCV

continued calibration verification

D

difference

DDT

dichlorodiphenyltrichloroethane

ICAL

initial calibration

ICV

initial calibration verification

IS

internal standard

RRT

relative retention time

RSD

relative standard deviation

RT

retention time

a See Analytical SOP References table (Table F-5).

January 2022

B-39

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Table B-9: Data Verification and Validation (Steps I and Ila/IIb) Process

Data Review Input

Description

Responsible for
Verification
(name, organization)

Step I/IIa/IIb a

Internal/External

Laboratory system audits

Determine whether the laboratory holds a
current DoD ELAP certification for all
analyses to be performed for the project.

Project Chemist
(Navy consultant)

Step I

Internal

Field procedures

Determine whether field procedures are
performed in accordance with this SAP and
prescribed procedures.

QA Program Manager
(Navy consultant)

Step I

Internal

Field logbook and notes

Review the field logbook and any field
notes on a weekly basis and place them in
the project file.

Copies of the field logbook and field notes
will be provided to the Navy consultant
CTO manager and included in the Field
Audit Report.

Field Manager
(Navy consultant)

Step I

Internal

Instrument calibration sheets

Determine whether instruments are
calibrated and used in accordance with
manufacturer's' requirements.

Project Chemist
(Navy consultant) &
Data Validator
(LDC)

Step I

Internal & External

CoC forms

Review CoC completed forms and verify
them against the corresponding packed
sample coolers.

A copy of each CoC will be placed in the
project file. The original CoC will be taped
inside the cooler for shipment to the
analytical laboratory.

Project Chemist
(Navy consultant)

Step I

Internal

Sampling analytical data
package

Verify all analytical data packages for
completeness prior to submittal of the data
to the data validator.

Laboratory Project

Manager

(APPL)

Step I

External

Analytes

Determine whether all analytes specified in
Table F-2 were analyzed and reported on
by the laboratory.

Project Chemist
(Navy consultant)

Step Ha

Internal

B-40

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Data Review Input

Description

Responsible for
Verification
(name, organization)

Step I/IIa/IIb a

Internal/External

CoC and field QC logbook

Examine data traceability from sample
collection to project data generation.

Project Chemist
(Navy consultant)

Step Ha

Internal

Laboratory data and SAP
requirements

Assess and document the performance of
the analytical process.

A summary of all QC samples and results
will be verified for measurement
performance criteria and completeness.
Full Validation will be performed on 10%
of the data and Standard Validation will be
performed on 90% of the data. A report
will be prepared within 21 days of receipt.

Data Validator
(LDC) &

Project Chemist
(Navy consultant)

Steps Ha & lib

Internal & External

VOCs

Complete Procedure II-B, Level C and
Level D Data Validation Procedure for
GC/MS Volatile Organics by SW-846
8260B (DON 2015).

Data Validator
(LDC)

Step Ha

External

PAHs and SVOCs

Complete Procedure II-C, Level C and
Level D data Validation Procedure for
GC/MS Semivolatile Organics by SW-846
8270C (Full Scan and SIM) (DON 2015).

Data Validator
(LDC)

Step Ha

External

TPH

Complete Procedure II-H, Level C and
Level D Data Validation Procedure for
Extractable Total Petroleum Hydrocarbons
by SW-846 8015B (DON 2015).

Data Validator
(LDC)

Step Ha

External

Sampling plan

Determine whether the number and type of
samples specified in Table F-l were
collected and analyzed.

Project Chemist
(Navy consultant) &
Field Manager
(Navy consultant)

Step lib

Internal

Field QC samples

Establish that the number of QC samples
specified in Table F-l were collected and
analyzed.

Project Chemist
(Navy consultant)

Step lib

Internal

B-41

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01

Appendix B

January 2022

Data Review Input

Description

Responsible for
Verification
(name, organization)

Step I/IIa/IIb a

Internal/External

Project quantitation limits and
data qualifiers

Establish that sample results met the
project quantitation limits and qualify the
data in accordance with Procedure II-A,

Data Validation Procedure (DON 2015).

Data Validator
(LDC) &

Project Chemist
(Navy consultant)

Step lib

Internal & External

Validation report

Summarize outcome of data comparison to
MPC in the SAP. Include qualified data
and an explanation of all data qualifiers.

Data Validator
(LDC)

Step Ha

External

MPC measurement performance criteria

a Ha	Compliance with methods, procedures, and contracts. See Table 10, page 117, UFP-QAPP manual, V. 1 (DoD 2005).

lib	Comparison with measurement performance criteria in the SAP. See Table 11, page 118, UFP-QAPP manual, V. 1 (DoD 2005).

B-42

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix C	

Appendix C - Standard Operating Procedures

(DON 2015)

-------
Site Characterization Plan

November 2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix C	

This page intentionally left blank

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Appendix B - Analytical Data Package Requirements for Chemical
Analyses

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

This page intentionally left blank

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

GC-FID Stage 4 Deliverables

Item No.

Deliverable

1

Chain of Custody

2

Sample results with analysis and extraction/preparation dates

3

Summary of MS/MSD/Duplicate recoveries and control limits (listing or link with associated
samples)

4

Summary of LCS/LCSD recoveries and control limits (listing or link with associated
samples)

5

Method blanks (listing or link with associated samples)

6

Summary of surrogate recoveries

7

Summary of initial calibration data (RF and %RSD, or r if applicable)

8

Summary of continuing calibration (%D)

9

Injection logs

10

Extraction/preparation logs

11

Case narrative to discuss anomalies

12

Raw data associated with the summary forms listed above

13

Raw data for item #2 which includes chromatograms, logbooks, quantitation reports, and
spectra

Note: The data deliverable package must have a table of contents and be paginated.

%D

percent difference

%RSD

percent relative standard deviation

GC-FID

gas chromatography-flame ionization detector

MS

matrix spike

MSD

matrix spike duplicate

LCS

laboratory control sample

LCSD

laboratory control sample duplicate

RF

response factor

B-l

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

GC-MS Stage 4 Deliverables

Item No.

Deliverable

1

Chain of Custody

2

Sample results with analysis and extraction/preparation dates

3

Summary of MS/MSD/Duplicate recoveries and control limits (listing or link with associated
samples)

4

Summary of LCS/LCSD recoveries and control limits (listing or link with associated
samples)

5

Method blanks (listing or link with associated samples)

6

Summary of instrument blanks - metals only (listing or link with associated samples)

7

Summary of surrogate recoveries

8

Summary of initial calibration data (RRF and %RSD, or r if applicable)

9

Summary of continuing calibration (%D and RRF)

10

Summary of internal standards (area response and retention time)

B-2

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Item No.

Deliverable

11

Summary of instrument tuning (listing or link with associated samples, must show 12-hour
clock)

12

Injection logs

13

Extraction/preparation logs

14

Case narrative to discuss anomalies

15

Raw data associated with the summary forms listed above

16

Raw data for item #2 which includes chromatograms, logbooks, quantitation reports, and
spectra

Note: The data deliverable package must have a table of contents and be paginated.
GC-MS gas chromatography-mass spectrometry
RRF relative response factor

General Chemistry Stage 4 Deliverables

Item No.

Deliverable

1

Chain of custody

2

Sample results with analysis and extraction/preparation dates

3

Summary of MS/MSD/Duplicate recoveries and control limits (listing or link with associated
samples)

4

Summary of LCS/LCSD recoveries and control limits (listing or link with associated
samples)

5

Method blanks (listing or link with associated samples)

6

Summary of initial calibration data (correlation coefficient, r)

7

Summary of continuing calibration (%D or % recovery), if applicable

8

Injection logs

9

Extraction/preparation logs, if applicable

10

Case narrative to discuss anomalies

11

Raw data associated with the summary forms listed above

12

Raw data for item #2, which includes logbooks, quantitation reports, and spectra

Note: The data deliverable package must contain a table of contents and be paginated.

B-3

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

HARD COPY DATA DELIVERABLES COMPACT DISK REQUIREMENTS

The compact disk (CD) shall contain exactly the same information as the hard copy data
deliverables (HDD) including amended and additional pages requested during data review and
validation. Upon completion of data review and validation by AECOM Technical Services, Inc.
or third-party, the laboratory shall be required to provide the CD with the following:

•	The images shall be clear and legible.

•	The images shall be right side up.

•	The images shall be straight.

•	The images shall be in the same order as the HDD.

•	Images may be submitted in PDF, TIFF, or other equivalent imaging format. Files shall be
burned for each page and each CD shall be indexed. The laboratory shall log in samples
based on project number, project name and sample delivery group (also known as batch or
work order).

•	If the images are not clear, legible, right side up, straight or in order, then the laboratory
shall resubmit the CD.

•	The CD label shall contain the following information:

-	Navy contract number

-	Contract task order name and number

-	Sample delivery group number

-	Matrices and methods

-	Date of submittal

B-4

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Appendix B. 2:

Field Sampling, Analytical, and
Quality Management Reference Tables

Table B-l: Location-Specific SamplingMethods/SOP Requirements
Table B-2: Analyte List and Reference Limits

Table B-3: Preparation and Analytical Requirements for Field and QC Samples

Table B-4: Analytical Services

Table B-5: Analytical SOP References

Table B-6: Laboratory QC Samples

Table B-7: Analytical Instrument and Equipment Maintenance, Testing, and Inspection
Table B-8: Analytical Instrument Calibration

Table B-9: Data Verification and Validation (Steps I and Ila/IIb) Process

B-5

-------
-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

APPENDIX B.2 - ACRONYMS AND ABBREVIATIONS

%D

percent difference

APPL

Agriculture & Priority Pollutants Laboratories, Inc.

BFB

4-bromofluorobenzene

CA

corrective action

CAS

Chemical Abstracts Service

CCB

continuing calibration blank

CCV

continued calibration verification

D

difference

DFTPP

decafluorotriphenylphosphine

DoD

Department of Defense

DQI

data quality indicator

DQO

data quality objective

EICP

extracted ion current profile

EPA

Environmental Protection Agency, United States

g

gram

GC

gas chromatography

GC-FID

gas chromatography-flame ionization detector

GC-MS

gas chromatography-mass spectrometry

H2SO4

sulfuric acid

HC1

hydrogen chloride

HNO3

nitric acid

ICAL

initial calibration

ICP-AES

inductively coupled plasma-atomic emission spectroscopy

ICV

initial calibration verification

IS

internal standard

L

liter

LCS

laboratory control sample

LDC

Laboratory Data Consultants

LOD

limit of detection

LOQ

limit of quantitation

MB

method blank

mg/kg

milligram per kilogram

mL

milliliter

MPC

measurement performance criteria

MS

matrix spike

MSD

matrix spike duplicate

N/A

not applicable

NaHS04

sodium bisulfate

NAPL

non-aqueous-phase liquid

NIST

National Institute of Standards and Technology

oz

ounce

PFTBA

perfluorotributylamine

QA

quality assurance

QC

quality control

QSM

Quality Systems Manual

RPD

relative percent difference

B-7

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

RRT

relative retention time

RSD

relative standard deviation

RT

retention time

SOP

standard operating procedure

TBD

to be determined

B-8

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Table B-l: Location-Specific Sampling Methods/SOP Requirements

Sampling Location/ID
Number

Matrix

Depth
(ft bgs)

Analytical Group

Number of Samples

Sampling SOP Reference

LFSB01, LFSB02,
LFSB03, LFSB04 plus
potential 10 additional
step-out borings

Unconsolidated Material

approx.
200

Chemical Analyses:
VOCs, PAHs, TPH-d

At each soil boring:
1 composite subsurface
soil sample of the entire
petroleum-impacted soil
core;

1 discrete subsurface soil
sample at the total depth
of the boring;

1 duplicate per 10
subsurface soil samples;
1 MS/MSD pair per 20
subsurface soil samples
1 trip blank per cooler
containing VOCs.

Procedure I-B-l Soil
Sampling

HTSB01, HTSB02,
HTSB03, HTSB04 plus
potential 10 additional
step-out borings

Unconsolidated Material

approx.
200

Chemical Analyses:
VOCs, PAHs, TPH-d

At each soil boring:
1 composite subsurface
soil sample of the entire
petroleum-impacted soil
core;

1 discrete subsurface soil
sample at the total depth
of the boring;

1 duplicate per 10
subsurface soil samples;
1 MS/MSD pair per 20
subsurface soil samples
1 trip blank per cooler
containing VOCs.

Procedure I-B-l Soil
Sampling

Notes: Procedures are from the Project Procedures Manual (DON 2015).

Actual number of unconsolidated material samples will be dependent on field observations during coring.

Volumes for field duplicate, and MS/MSD samples will only be collected if sufficient unconsolidated material is present at each sampling interval. If limited
volume is present, collecting volume for VOCs, PAHs, and TPH will take priority.

B-9

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

One trip blank will be collected during each unconsolidated material sampling event.

TPH with silica gel cleanup will only be analyzed for sample with detections of TPH-d and TPH-o from the non-silica gel cleaned extract.

B-10

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Table B-2: Location-Specific Sampling Methods/SOP Requirements

B-l 1

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Matrix Unconsolidated Material











Laboratory-Specific Limits (mg/kg)

Analyte

CAS Number

Screenin g Criterion

a

(mg/kg)

Project LOQGoal
(mg/kg)

Project LODGoal
(mg/kg)

LOQ

LOD

DL

TPH

TPH-g(C5-Cl 1)

-3547

100

33

10

TBD

TBD

TBD

TPH-d (C10-C24)

-3527

220

73

22

TBD

TBD

TBD

VOCs

Benzene

71-43-2

0.30

0.10

0.030

TBD

TBD

TBD

Ethylbenzene

100-41-4

3.7

1.2

0.37

TBD

TBD

TBD

Toluene

108-88-3

3.2

1.1

0.32

TBD

TBD

TBD

Total Xylenes

1330-20-7

2.1

0.70

0.21

TBD

TBD

TBD

PAHs

1 -Methylnaphthalene

90-12-0

4.2

1.4

0.42

TBD

TBD

TBD

2 -Methylnaphthalene

91-57-6

4.1

1.4

0.41

TBD

TBD

TBD

Naphthalene

91-20-3

4.4

1.5

0.44

TBD

TBD

TBD

Notes:

mg/kg milligrams per kilogram
a DOH Tier 1 EALs (Summer 2016, updated January 2017),

B-12

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Table B-3: Preparation and Analytical Requirements for Field and QC Samples

Matrix

Analytical Group

Preparation Reference/Method SOP
Analytical Reference/Method SOP

Containers

Sample
Volume

Preservation
Requirement

Maximum Holding
Time

(preparation/analy sis)

Unconsolidated
Material

TPH-g, VOCs

Preparation Method: EPA 5035C
Preparation SOP: ANA8260
Analysis Method: EPA 8260C
Analysis SOP: ANA8260

2x1 OmL water-
preserved; 1 x 5mL
methanol-preserved;
Teflon-lined septum
caps

40 mL

Cool to <6°C

7 days (water-
preserved); 14 days
(methanol -preserved)



TPH-d, TPH-o

Preparation Method: EPA 3550C
Preparation SOP: SON004
Analysis Method: EPA 8015C
Analysis SOP: ANA8015

1 x 8-oz glass jar,
Teflon-lined lid

30 g

Cool to <6°C

Samples extracted
within 14 days and
analyzed within 40
days following
extraction.



TPH-d, TPH-o with
Silica Gel Cleanup

Preparation Method: EPA 3550C/EPA 3630
Preparation SOP: SON004/CLN004
Analysis Method: EPA 8015C
Analysis SOP: ANA8015



30 g

Cool to <6°C

Samples extracted
within 14 days and
analyzed within 40
days following
extraction.



PAHs

Preparation Method: EPA 3550C
Preparation SOP: SON009
Analysis Method: EPA 8270D SIM
Analysis SOP: ANA8270SIM



30 g

Cool to <6°C

Samples extracted
within 14 days and
analyzed within 40
days following
extraction.

Notes:

g

gram

H2SO4

sulfuric acid

HC1

hydrogen chloride

L

liter

mL

milliliter

NaHS04

sodium bisulfate

oz

ounce

B-13

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Table B-4: Analytical Services

Matrix

Analytical Group

Sampling Locations/
ID Numbers

Analytical SOP

Data Package
Turnaround Time

Labor atory/Organizati on
(name and address)

Unconsolidated
Material

VOCs (BTEX)

TPH-g, TPH-d,

PAHs (1-methylnaphthalene,
2-methylnaphthalene, naphthalene)

LFSB01, LFSB02,
LFSB03, LFSB04 plus
potential 10 additional
step-out borings;
HTSB01, HTSB02,
HTSB03, HTSB04
plus potential 10
additional step-out
borings

ANA8260,
ANA8015,
ANA8270SIM

14 days after
samples are
received at
laboratory

TBD

a Laboratory meets DOD ELAP or AASHTO accreditation requirements, as applicable, to support project needs.

B-14

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Table B-5: Analytical SOP References

Laboratory: TBD

Point of Contact: TBD

Point of Contact Phone Number: TBD

Lab SOP Number

Title, Revision Date, and/or Number

Definitive or
Screening Data

Matrix and Analytical
Group

Instrument

Variance to QSM
(Yes/No)

Modified for Project
Work? (Yes/No)

Preparatory
Methods

ANA8260

Analysis Of Water/Soil/Sludge By
EPA Method 8260, Rev 22, 4/4/18

Definitive

VOCs, TPH-g
(Unconsolidated
Material, Water)

Preparation

No

No

SONOOl

Soni cation Extraction of Soil, Sludge,
and Solid (EPA Method 3550C), Rev
5, 0907/18

Definitive

TPH-d, TPH-o, PAHs

(Unconsolidated

Material)

Preparation

No

No

CLN004

3630C Silica Gel Cleanup, Rev 2,
12/22/16

Definitive

TPH-d, TPH-o
Silica Gel Cleanup
(Unconsolidated
Material)

Preparation

No

No

Analytical
Methods

ANA8260

Analysis Of Water/Soil/Sludge By
EPA Method 8260, Rev 22, 4/4/18

Definitive

VOCs, TPH-g
(Unconsolidated
Material, Water)

GC-MS

No

No

ANA8015

Determination Of Total Extractable
Petroleum Hydrocarbons (TPH) In
Water, Sludges And Soils By GC-
FID, Rev 11, 4/4/18

Definitive

TPH-d, TPH-o
(Unconsolidated
Material, Water)

GC-FID

No

No

ANA8270SIM

PAH By SIM By EPA Method
8270, Rev 8, 12/26/17

Definitive

PAHs

(Unconsolidated
Material, Water)

GC-MS

No

No

Note: The laboratory SOPs listed in the table are the most current revisions at the time of publication of this MWIWP Addendum 03. The Navy consultant will
review the laboratory SOPs immediately prior to sample submittal to ensure that the laboratory uses SOPs that are in compliance with the DoD QSM annual
review requirement.

GC-FID gas chromatography-flame ionization detector

B-15

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

GC-MS gas chromatography-mass spectrometry

ICP-AES inductively coupled plasma-atomic emission spectroscopy

B-16

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Table B-6: Laboratory QC Samples

Matrix

Analytical Group

Analytical Method/SOP Reference
Analytical Organization

for Chemistry Analyses

Unconsolidated Material
VOCs, TPH-g

Analytical Method: SW-846 8260C
Preparation Method: EPA5035A, EPA 5030B
Laboratory SOPs: ANA8260

TBD

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOD

determination
and verification

At initial set-up and
verified quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOD must
be verified on each.

The apparent signal to
noise ratio must be at
least 3 and the results
must meet all method
requirements for analyte
identification.

If the LOD verification fails,
the laboratory must:

1)	Repeat the detection limit
determination and LOD
verification at a higher
concentration; or

2)	Perform and pass two
consecutive LOD verifications
at a higher concentration. The
LOD is set at the higher
concentration.

Analyst
Lab QA
Officer
Project
Chemist

Bias/

Representative-
ness

QC acceptance criteria
as specified by Lab SOP
ANA8260.

B-17

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOQ

establishment
and verification

At initial setup:

1)	Verify LOQ; and

2)	Determine precision
and bias at the LOQ.
Subsequently, verify
LOQ quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOQ must
be verified on each.

1)	The LOQ and
associated precision and
bias must meet client
requirements and must
be reported; or

2)	In the absence of
client requirements,
must meet control limits
oftheLCS.

3)	If the method is
modified, precision and
bias at the new LOQ
must be demonstrated
and reported. See
Volume 1, Module 4,
Section 1.5.2 of the
DoD QSM 5.4 (DoD
and DOE 2021).

If the LOQ verification fails,
the laboratory must either
establish a higher LOQ or
modify method to meet the
client-required precision and
bias.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

QC acceptance criteria
as specified by Lab SOP
ANA8260 and at least
as stringent as specified
by DoD QSM 5.4 (DoD
and DOE 2021).

Tune check

Prior to the ICAL and
prior to each 12-hour
period of sample
analysis.

Specific ion abundance
criteria of BFB or
DFTPP from method.

Retune instrument and verify.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No samples may be
analyzed without a
passing tune.

B-18

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

ccv

Before sample analysis,
after every 10 field
samples, after every 12
hours of analysis time,
and at the end of the
analysis sequence.

All reported analytes
and surrogates within
established RT
windows. All reported
analytes and surrogates
within ±20% of true
value. All reported
analytes and surrogates
within ±50% for the end
of the analytical batch
CCV.

Immediately analyze two
additional consecutive CCVs.
If both pass, samples may be
reported without reanalysis. If
either fails, take corrective
action(s) and re-calibrate; then
reanalyze all affected samples
since the last acceptable CCV.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

Results may not be
reported without a valid
CCV. If reanalysis
cannot be performed,
data must be qualified
and explained in the
case narrative. If the
specific version of a
method requires
additional evaluation
(e.g., average response
factors) these additional
requirements must also
be met.

MB

Each time analytical
batch.

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher. For
common lab
contaminants, no
analytes detected
>LOQ.

Correct problem. If required,
re-prep and reanalyze MB and
all samples processed with the
contaminated blank.

Analyst
Lab QA
Officer
Project
Chemist

Bias

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher.
For common laboratory
contaminants, no
analytes detected
>LOQ.

LCS

One per batch of at most
20 samples analyzed of
similar matrix per
analytical method.

Per DoD QSM
Appendix C Limits,
Method SW-846 8260C
and Lab SOP
ANA8260.

Correct problem. If required,
re-prep and reanalyze the LCS
and all samples processed in
the associated preparatory
batch for the failed analytes.
Results may not be reported
without a valid LCS.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

B-19

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

MS/MSD pair

One per analytical
method for each batch of
at most 20 samples.

Per DoD QSM
Appendix C Limits,
Method SW-846 8260C
and Lab SOP
ANA8260.

MSD or Matrix
Duplicate: RPD of all
analytes <20%.

Examine the PQOs. Notify
Lab QA officer and project
chemist about additional
measures to be taken.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

For matrix evaluation,
use QC acceptance
criteria at least as
stringent as specified by
DoD QSM 5.4 (DoD
and DOE 2021).

Internal

standards

verification

Every field sample,
standard, and QC
sample.

Retention time ±10
seconds from retention
time of the midpoint
standard in the ICAL;
EICP area within -50%
to+100% of ICAL
midpoint standard.

Inspect mass spectrometer and
GC for malfunctions.
Reanalysis of samples
analyzed while system was
malfunctioning is mandatory.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

Laboratory in-house
method manual to be
followed for acceptance
criteria.

Surrogate spike

All field and QC
samples.

Per DoD QSM
Appendix C Limits,
Method SW-846 8260C
and Lab SOP
ANA8260.

For QC and field samples,
correct problem then re-prep
and reanalyze all failed
samples for failed surrogates
in the associated preparatory
batch, if sufficient sample
material is available. If
obvious chromatographic
interference with surrogate is
present, reanalysis may not be
necessary.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

Trip blank

1 per cooler.

Target analytes <1/2
LOQ.

Reanalyze for confirmation
through a second analysis of
the trip blank. Examine the
PQOs.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/Bias,
Representative-
ness/Contaminat
ion

Target analytes <1/2
LOQ.

B-20

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Matrix	Unconsolidated Material

Analytical Group	TPH-d, TPH-o with and without Silica Gel Cleanup

Analytical Method/SOP Reference	Analytical Method: EPA Method 8015C

Preparation Method: EPA3550C/3630C, EPA3510C/3630C
Laboratory SOPs: SON001 ,CLN004, SEP11 .ANA8015

Analytical Organization	TBD

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance
Criteria

LOD

determination
and verification

At initial set-up and
verified quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOD must
be verified on each.

The apparent signal to
noise ratio must be at
least 3 and the results
must meet all method
requirements for analyte
identification.

If the LOD verification fails,
the laboratory must:

1)	Repeat the detection limit
determination and LOD
verification at a higher
concentration; or

2)	Perform and pass two
consecutive LOD verifications
at a higher concentration. The
LOD is set at the higher
concentration.

Analyst
Lab QA
Officer
Project
Chemist

Bias/

Representative-
ness

QC acceptance criteria
as specified by Lab SOP
ANA8015.

B-21

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance
Criteria

LOQ

establishment
and verification

At initial setup:

1)	Verify LOQ; and

2)	Determine precision
and bias at the LOQ.
Subsequently, verify
LOQ quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOQ must
be verified on each.

1)	The LOQ and
associated precision and
bias must meet client
requirements and must
be reported; or

2)	In the absence of
client requirements,
must meet control limits
oftheLCS.

3)	If the method is
modified, precision and
bias at the new LOQ
must be demonstrated
and reported. See
Volume 1, Module 4,
Section 1.5.2 of the DoD
QSM5.4 (DoD and
DOE 2021).

If the LOQ verification fails,
the laboratory must either
establish a higher LOQ or
modify method to meet the
client-required precision and
bias.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

QC acceptance criteria
as specified by Lab SOP
ANA8015, and at least
as stringent as specified
by DoD QSM 5.4 (DoD
and DOE 2021).

ccv

Before sample analysis,
after every 10 field
samples, and at the end
of the analysis sequence.

All reported analytes
and surrogates within
established RT
windows. All reported
analytes and surrogates
within ±20% of true
value.

Immediately analyze two
additional consecutive CCVs.
If both pass, samples may be
reported without reanalysis. If
either fails, take corrective
action(s) and re-calibrate; then
reanalyze all affected samples
since the last acceptable CCV.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

Results may not be
reported without a valid
CCV. If reanalysis
cannot be performed,
data must be qualified
and explained in the
case narrative.

B-22

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance
Criteria

MB

Each time samples are
extracted and one per
matrix per analytical
method for each batch of
at most 20 samples.

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher. For
common lab
contaminants, no
analytes detected >LOQ.

Correct problem. If required,
re-prep and reanalyze MB and
all samples processed with the
contaminated blank.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher.
For common laboratory
contaminants, no
analytes detected
>LOQ.

LCS

One per batch of at most
20 samples analyzed of
similar matrix per
analytical method.

Per DoD QSM
Appendix C Limits,
Method 8015C and Lab
SOP ANA8015.

Correct problem. If required,
re-prep and reanalyze the LCS
and all samples processed in
the associated preparatory
batch for the failed analytes.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

Internal

standards

verification

Every field sample,
standard, and QC
sample.

Retention time ±30
seconds from retention
time of the midpoint
standard in the ICAL;
EICP area within -50%
to+100% of ICAL
midpoint standard.

Inspect mass spectrometer and
GC for malfunctions.
Reanalysis of samples
analyzed while system was
malfunctioning is mandatory.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

Laboratory in-house
method manual to be
followed for acceptance
criteria.

B-23

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance
Criteria

Surrogate spike

All field and QC
samples.

Per DoD QSM
Appendix C Limits,
Method 8015C and Lab
SOP ANA8015.

For QC and field samples,
correct problem then re-prep
and reanalyze all failed
samples for failed surrogates
in the associated preparatory
batch, if sufficient sample
material is available. If
obvious chromatographic
interference with surrogate is
present, reanalysis may not be
necessary.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

Surrogate spike
for silica gel
cleanup
procedure

All field and QC
samples.

Acceptable recovery
range of 0 to 1% of
spiked amount of polar
hydrocarbon surrogate.

For QC and field samples, if
sufficient sample extract is
available, re-run extracts
through silica gel cleanup
procedure and reanalyze all
failed samples for failed
surrogates in the associated
preparatory batch. Otherwise,
re-extract samples and re-run
silica gel cleanup on re-extract
prior to re-analysis, if
sufficient sample material is
available.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

Polar hydrocarbon
surrogate recovered at
<1% of spiked amount.

MS/MSD pair

One per analytical
method for each batch of
at most 20 samples.

Per DoD QSM
Appendix C Limits,
Method 8015C and Lab
SOP ANA8015.
MSD or Matrix
Duplicate: RPD of all
analytes <30%.

Examine the PQOs. Notify
Lab QA officer and project
chemist about additional
measures to be taken.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

For matrix evaluation,
use QC acceptance
criteria at least as
stringent as specified by
DoD QSM 5.4 (DoD
and DOE 2021).

B-24

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Matrix	Unconsolidated Material

Analytical Group	PAHs

Analytical Method/SOP Reference	Analytical Method: EPA Method 8270D SIM

Preparation Method: EPA3550C, EPA 3510C
Laboratory SOPs: SON001, SEP004, ANA8270SIM

Analytical Organization	TBD

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOD

determination
and verification

At initial set-up and
verified quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOD must
be verified on each.

The apparent signal to
noise ratio must be at
least 3 and the results
must meet all method
requirements for analyte
identification.

If the LOD verification fails,
the laboratory must:

1)	Repeat the detection limit
determination and LOD
verification at a higher
concentration; or

2)	Perform and pass two
consecutive LOD verifications
at a higher concentration. The
LOD is set at the higher
concentration.

Analyst
Lab QA
Officer
Project
Chemist

Bias/

Representative-
ness

QC acceptance criteria
as specified by Lab SOP
ANA8270SIM.

B-25

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOQ

establishment
and verification

At initial setup:

1)	Verify LOQ; and

2)	Determine precision
and bias at the LOQ.
Subsequently, verify
LOQ quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOQ must
be verified on each.

1)	The LOQ and
associated precision and
bias must meet client
requirements and must
be reported; or

2)	In the absence of
client requirements,
must meet control limits
oftheLCS.

3)	If the method is
modified, precision and
bias at the new LOQ
must be demonstrated
and reported. See
Volume 1, Module 4,
Section 1.5.2 of the DoD
QSM5.4 (DoD and
DOE 2021).

If the LOQ verification fails,
the laboratory must either
establish a higher LOQ or
modify method to meet the
client-required precision and
bias.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

QC acceptance criteria
as specified by Lab SOP
ANA8270SIM, and at
least as stringent as
specified by DoD
QSM5.4 (DoD and
DOE 2021).

Performance
check

Before ICAL and sample
analysis, and at the
beginning of each 12-
hour shift.

Degradation of DDT
must be <20%.
Benzidine and
pentachlorophenol will
be present at their
normal responses and
will not exceed a tailing
factor of 2.

Correct problem, then repeat
performance checks.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

Degradation of DDT
must be <20%; and
benzidine and
pentachlorophenol must
be present at normal
responses and tailing
factor is <2. No samples
must be analyzed until
performance check is
within criteria.

B-26

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

Tune Check

Prior to the ICAL and
prior to each 12-hour
period of sample
analysis.

Specific ion abundance
criteria of BFB or
DFTPP from method.

Retune instrument and verify

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No samples may be
analyzed without a
passing tune.

ccv

Before sample analysis,
after every 10 field
samples, after every 12
hours of analysis time,
and at the end of the
analysis sequence.

All reported analytes
and surrogates within
established RT
windows. All reported
analytes and surrogates
within ±20% of true
value.

Immediately analyze two
additional consecutive CCVs.
If both pass, samples may be
reported without reanalysis. If
either fails, take corrective
action(s) and re-calibrate; then
reanalyze all affected samples
since the last acceptable CCV.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

Results may not be
reported without a valid
CCV. If reanalysis
cannot be performed,
data must be qualified
and explained in the
case narrative.

MB

Each time samples are
extracted and one per
matrix per analytical
method for each batch of
at most 20 samples.

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher. For
common lab
contaminants, no
analytes detected >LOQ.

Correct problem. If required,
re-prep and reanalyze MB and
all samples processed with the
contaminated blank.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher.
For common laboratory
contaminants, no
analytes detected
>LOQ.

LCS

One per batch of at most
20 samples analyzed of
similar matrix per
analytical method.

Per DoD QSM
Appendix C Limits,
Method 8270D SIM and
Lab SOP
ANA8270SIM.

Correct problem. If required,
re-prep and reanalyze the LCS
and all samples processed in
the associated preparatory
batch for the failed analytes.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

B-27

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

Internal

standards

verification

Every field sample,
standard, and QC
sample.

Retention time ±10
seconds from retention
time of the midpoint
standard in the ICAL;
EICP area within -50%
to+100% of ICAL
midpoint standard.

Inspect mass spectrometer and
GC for malfunctions.
Reanalysis of samples
analyzed while system was
malfunctioning is mandatory.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

Laboratory in-house
method manual to be
followed for acceptance
criteria.

Surrogate spike

All field and QC
samples.

Per DoD QSM
Appendix C Limits,
Method 8270D SIM and
Lab SOP
ANA8270SIM.

For QC and field samples,
correct problem then re-prep
and reanalyze all failed
samples for failed surrogates
in the associated preparatory
batch, if sufficient sample
material is available. If
obvious chromatographic
interference with surrogate is
present, reanalysis may not be
necessary.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision/
Representative-
ness

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

MS/MSD pair

One per analytical
method for each batch of
at most 20 samples.

Per DoD QSM
Appendix C Limits,
Method 8270D SIM and
Lab SOP
ANA8270SIM.

MSD or Matrix
Duplicate: RPD of all
analytes <20%.

Examine the PQOs. Notify
Lab QA Officer and project
chemist about additional
measures to be taken.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy/
Precision

For matrix evaluation,
use QC acceptance
criteria at least as
stringent as specified by
DoD QSM 5.4 (DoD
and DOE 2021).

B-28

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

LOD

determination
and verification

At initial set-up and
verified quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOD must
be verified on each.

The apparent signal to
noise ratio must be at
least 3 and the results
must meet all method
requirements for analyte
identification.

If the LOD verification fails,
the laboratory must:

1)	Repeat the detection limit
determination and LOD
verification at a higher
concentration; or

2)	Perform and pass two
consecutive LOD verifications
at a higher concentration. The
LOD is set at the higher
concentration.

Analyst
Lab QA
Officer
Project
Chemist

Bias/

Representative-
ness

QC acceptance criteria
as specified by Lab SOP
TBD.

LOQ

establishment
and verification

At initial setup:

1)	Verify LOQ; and

2)	Determine precision
and bias at the LOQ.
Subsequently, verify
LOQ quarterly. If a
laboratory uses multiple
instruments for a given
method, the LOQ must
be verified on each.

1)	The LOQ and
associated precision and
bias must meet client
requirements and must
be reported; or

2)	In the absence of
client requirements,
must meet control limits
oftheLCS.

3)	If the method is
modified, precision and
bias at the new LOQ
must be demonstrated
and reported. See
Volume 1, Module 4,
Section 1.5.2 of the DoD
QSM5.4 (DoD and
DOE 2021).

If the LOQ verification fails,
the laboratory must either
establish a higher LOQ or
modify method to meet the
client-required precision and
bias.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

QC acceptance criteria
as specified by Lab SOP
TBD, and at least as
stringent as specified by
DoD QSM 5.4 (DoD
and DOE 2021).

B-29

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

QC Sample

Frequency & Number

Method/SOP QC
Acceptance Limits

Corrective Action

Personnel
Responsible
for Corrective
Action

DQI

Measurement
Performance Criteria

MB

Each time samples are
extracted and one per
matrix per analytical
method for each batch of
at most 20 samples.

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher. For
common lab
contaminants, no
analytes detected >LOQ.

Correct problem. If required,
re-prep and reanalyze MB and
all samples processed with the
contaminated blank.

Analyst
Lab QA
Officer
Project
Chemist

Sensitivity/Bias

No analytes detected
>1/2 LOQ or >1/10 the
amount measured in any
sample or 1/10 the
regulatory limit,
whichever is higher.
For common laboratory
contaminants, no
analytes detected
>LOQ.

LCS

One per batch of at most
20 samples analyzed of
similar matrix per
analytical method.

Per DoD QSM
Appendix C Limits,
Method TBD and Lab
SOP TBD.

Correct problem. If required,
re-prep and reanalyze the LCS
and all samples processed in
the associated preparatory
batch for the failed analytes.

Analyst
Lab QA
Officer
Project
Chemist

Accuracy

QC acceptance criteria
at least as stringent as
specified by DoD
QSM 5.4 (DoD and
DOE 2021).

Note: No laboratory QC samples are generated for geotechnical and petrographic analyses.

B-30

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Table B-7: Analytical Instrument and Equipment Maintenance, Testing, and Inspection

Instrument/
Equipment

Maintenance
Activity

Testing
Activity

Inspection
Activity

Frequency

Acceptance
Criteria

Corrective
Action

Responsible Person

SOP Referencea

GC-FID and
GC-MS

Change gas
purifier.

N/A

Visually inspect
if traps are
changing color.

Every 6-12
months

No moisture

Replace
indicating traps.

Analyst or certified

instrument

technician

ANA8015,

ANA8270SIM,

ANA8270

Change

syringes/syringe
needles.

N/A

Visually inspect
for wear or
damage.

Every 3 months

N/A

Replace syringe
if dirt is
noticeable in
the syringe.

Analyst or certified

instrument

technician

Change inlet liner,
liner O-rings, and
inlet septum.

N/A

Visually inspect
for dirt or
deterioration.

Weekly for
liner

Monthly for 0-
rings
Daily for
septum

N/A

Replace and
check often.

Analyst or certified

instrument

technician

Change front-end
column.

N/A

Check peak
tailing,
decreased
sensitivity,
retention time
changes, etc.

Weekly,
monthly, or
when needed

N/A

Remove 1/2 to
1 meter from
the front of the
column when
experiencing
problems.

Analyst or certified

instrument

technician

Clean injector
ports.

N/A

N/A

As needed

N/A

N/A

Analyst

Replace trap on
purge-and-trap
systems.

N/A

N/A

Bi-monthly or
as needed

N/A

N/A

Analyst

Replace columns.

N/A

N/A

If

chromatograms
indicate
possible
contamination

N/A

N/A

Analyst

B-31

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Instrument/
Equipment

Maintenance
Activity

Testing
Activity

Inspection
Activity

Frequency

Acceptance
Criteria

Corrective
Action

Responsible Person

SOP Referencea

GC-FID

Replace detector
jets.

N/A

N/A

As needed

N/A

N/A

Analyst

ANA8015



Replace

hydrocarbon traps
and oxygen traps
on helium and
hydrogen gas lines.

N/A

N/A

Every 4-6
months

N/A

N/A

Analyst





Replace chemical
trap.

N/A

N/A

Yearly or as
needed

N/A

N/A

Analyst





Replace converter
tube in gas purifier
system.

N/A

N/A

Yearly or as
needed

N/A

N/A

Analyst



B-32

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Instrument/
Equipment

Maintenance
Activity

Testing
Activity

Inspection
Activity

Frequency

Acceptance
Criteria

Corrective
Action

Responsible Person

SOP Referencea

GC-MS

Change tune MSD,
check the
calibration vial,
and replace the
foreline pump oil.

N/A

Visually inspect
and monitor the
fluid becoming
discolored.

As needed or
every 6 months

In accordance
with

manufacturer's
recommendatio
n or lab SOP

Keep plenty of
PFTBA; refill
the vial and
check the fluid;
change when
the fluid
becomes
discolored.

Analyst or certified

instrument

technician

ANA8270SIM,
ANA8270



Run tuning
program to
determine if source
is functioning
properly.

N/A

N/A

Daily

N/A

Cool system,
vent,

disassemble,
and clean.

Analyst

ANA8270SIM,
ANA8270



N/A

Tune

instrument.

N/A

Daily or every
12 hours

Per method

Liner and septa
are replaced;
tune file used is
manually
adjusted.

Analyst





Vacuum rough
pump oil level is
checked.

N/A

N/A

Every 4-6
weeks

N/A

Add oil if
needed.

Analyst





Replace/refill
carrier gas line
oxygen and
moisture traps.

N/A

N/A

Yearly or as
needed

N/A

N/A

Analyst



Water Bath
(Precision
Microprocess
or controlled)

Check instrument
connections, water
level, and
thermometer.

Measure water
temperature
against a
calibrated
thermometer.

Visually inspect
for wear or
damage and
indicator from
computer
controls.

Daily and
annual
maintenance
from

manufacturer

Refer to
manufacturer's
recommendatio
n

Return to
manufacturer
for recalibration
or call for
maintenance
service.

Analyst or certified

instrument

technician

INS 001

B-33

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Instrument/
Equipment

Maintenance
Activity

Testing
Activity

Inspection
Activity

Frequency

Acceptance
Criteria

Corrective
Action

Responsible Person

SOP Referencea

Drying Oven

Thermometer
indicator.

Measure oven
temperature
against a
calibrated
thermometer.

Visually inspect
for wear or
damage and
indicator from
computer
controls.

Daily and
annual
maintenance
from

manufacturer

Refer to
manufacturer's
recommendatio
n

Return to
manufacturer
for recalibration
or call for
maintenance
service.

Analyst or certified

instrument

technician

INO003

Analytical
Balance

Check digital LCD
display and ensure
a flat base for the
Instrument.

Calibrate
against
verified
(NIST) mass.

Visually inspect
for wear or
damage and
indicator from
computer
controls.

Daily and
annual
maintenance
from

manufacturer

Refer to
manufacturer's
recommendatio
n

Return to
manufacturer
for recalibration
or call for
maintenance
service.

Analyst or certified

instrument

technician

INO011

pH Meter

Check LCD
display and pH
probe.

3 point
calibration
using known
standards.

Visually inspect
for wear or
damage and
indicator from
computer
controls.

Daily and
annual
maintenance
from

manufacturer

±0.05 units

Return to
manufacturer
for recalibration
or call for
maintenance
service.

Analyst or certified
manufacture
instrument
technician

INO038

Note: No instrument and equipment maintenance, testing, and inspection criteria for geotechnical and petrographic analyses.
N/A not applicable

NIST National Institute of Standards and Technology
PFTBA perfluorotributylamine
a See Analytical SOP References table (Table F-5).

B-34

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Table B-8: Analytical Instrument Calibration

Instrument

Calibration Procedure

Frequency of
Calibration

Acceptance Criteria

Corrective Action

Person Responsible
for Corrective Action

SOP Reference

a

GC-MS
EPA Methods
8260C, 8720D
SIM

Tuning

Prior to ICAL and at
the beginning of each
12-hour period

Refer to method for
specific ion criteria.

Retune instrument and
verify. Rerun affected
samples.

Lab Manager/Analyst
or certified instrument
technician

ANA8270SIM,
ANA8270



Breakdown check (DDT-Method
8270 only)

At the beginning of
each 12-hour period,
prior to analysis of
samples

Degradation <20% for
DDT. Benzidine and
pentachl or ophenol
should be present at
their normal responses
and should not exceed a
tailing factor of 2.

Correct problem, then
repeat breakdown
checks.

Lab Manager/Analyst
or certified instrument
technician





Minimum 5-point ICAL
for linear calibration
Minimum 6-point ICAL
for quadratic calibration

Prior to sample
analysis

RSD for each analyte
<15% or least square
regression>0.995. Non-
linear least squares
regression (quadratic)
for each analyte <0.995.

Correct problem then
repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician





Second source
calibration verification

After ICAL

All analytes within
±20% of expected value.

Correct problem and
verify second source
standard; rerun second
source verification. If
fails, correct problem
and repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician





RT window position for
each analyte and
surrogate

Once per ICAL

Position will be set
using the midpoint
standard for the ICAL.

N/A

Lab Manager/Analyst
or certified instrument
technician



B-35

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Instrument

Calibration Procedure

Frequency of
Calibration

Acceptance Criteria

Corrective Action

Person Responsible
for Corrective Action

SOP Reference

a



RRT

With each sample

RRT of each target
analyte in each
calibration standard
within ±0.06 RRT units
of ICAL.

Correct problem, then
reanalyze all samples
analyzed since the last
RT check. If fails, then
rerun ICAL and
samples.

Lab Manager/Analyst
or certified instrument
technician





CCV

Daily, before sample
analysis, unless ICAL
performed same day
and after every
10 samples and at the
end of the analysis
sequence

All analytes within
±20% of expected value
(%D).

All reported analytes
and surrogates within
±50% for end of
analytical batch CCV.

Immediately analyze
two additional
consecutive CCVs. If
both pass, samples may
be reported without
reanalysis. If either fails,
take corrective action(s)
and re-calibrate; then
reanalyze all affected
samples since the last
acceptable CCV.

Lab Manager/Analyst
or certified instrument
technician





IS

Each CCV and sample

RT ±10 seconds from
RT of the ICAL mid-
point standard. EICP
area within -50% to
+100% of area from IS
in ICAL mid-point
standard.

Inspect mass
spectrometer and GC for
malfunctions.

Reanalysis of samples
analyzed during failure
is mandatory.

Lab Manager/Analyst
or certified instrument
technician



B-36

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Instrument

Calibration Procedure

Frequency of
Calibration

Acceptance Criteria

Corrective Action

Person Responsible
for Corrective Action

SOP Reference

a

GC-FID
EPA Method
8015C

Minimum 5-point ICAL
for linear calibration
Minimum 6-point ICAL
for quadratic calibration

Prior to sample
analysis

RSD for each analyte
<20% or least square
regression>0.995. Non-
linear least squares
regression (quadratic)
for each analyte <0.995.

Correct problem then
repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician

ANA8015



Second source
calibration verification

Once after each ICAL

Analytes within ±20%
of expected value (initial
source), and within
established RT
windows.

Correct problem and
verify second source
standard. Rerun second
source verification. If
fails, correct problem
and repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician





RT window width

At method set-up and
after major
maintenance

RT width is ±3 times
standard deviation for
each analyte RT from
72-hour study. For TPH-
d: calculate RT based on
C12 and C25 alkanes.

N/A

Lab Manager/Analyst
or certified instrument
technician





Establishment and
verification of the RT
window for each analyte
and surrogate

Once per ICAL and at
the beginning of the
analytical shift for
establishment of RT;
and with each CCV for
verification of RT

Using the midpoint
standard or the CCV at
the beginning of the
analytical shift for RT
establishment; and
analyte must fall within
established window
during RT verification.

N/A

Lab Manager/Analyst
or certified instrument
technician





Run second source
calibration verification
(ICY)

ICV: Daily, before
sample analysis, unless
ICAL performed same
day

All analytes within
±20% of expected value
(%D).

Correct problem and
rerun ICV. If fails,
repeat ICAL.

Lab Manager/Analyst
or certified instrument
technician



B-37

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Instrument

Calibration Procedure

Frequency of
Calibration

Acceptance Criteria

Corrective Action

Person Responsible
for Corrective Action

SOP Reference

a



ccv

Daily, before sample
analysis, unless ICAL
performed same day
and after every
10 samples and at the
end of the analysis
sequence

All analytes within
±20% of expected value
(%D).

Immediately analyze
two additional
consecutive CCVs. If
both pass, samples may
be reported without
reanalysis. If either fails,
take corrective action(s)
and re-calibrate; then
reanalyze all affected
samples since the last
acceptable CCV.

Lab Manager/Analyst
or certified instrument
technician



Water Bath

Measure water
temperature against a
calibrated thermometer

Annually

In accordance with unit
model and
manufacturer's
recommendation or
laboratory SOP.

Terminate analysis,
recalibrate, and verify
before sample analysis.

Lab Manager/Analyst
or certified instrument
technician

INS 001

Drying Oven

Measure oven
temperature against a
calibrated thermometer

Annually

In accordance with unit
model and
manufacturer's
recommendation or
laboratory SOP.

Terminate analysis,
recalibrate, and verify
before sample analysis.

Lab Manager/Analyst
or certified instrument
technician

INO003

Analytical
Balance

Calibrate against
verified (NIST) mass

Daily or prior to
analyzing samples

In accordance with unit
model and
manufacturer's
recommendation or
laboratory SOP.

Terminate analysis,
recalibrate, and verify
before sample analysis.

Lab Manager/Analyst
or certified instrument
technician

INO011

pH Meter

Run a minimum 3-point
calibration; run CCV

Daily or prior to
analyzing samples; one
CCV for every
10 samples

±0.05 unit.

Terminate analysis,
recalibrate, and verify
before sample analysis.

Lab Manager/Analyst
or certified instrument
technician

INO038

Note: No instrument calibration procedures for geotechnical and petrographic analyses.

B-38

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01

Appendix B	

%D

percent difference

CA

corrective action

CCV

continued calibration verification

D

difference

DDT

dichlorodiphenyltrichloroethane

ICAL

initial calibration

ICV

initial calibration verification

IS

internal standard

RRT

relative retention time

RSD

relative standard deviation

RT

retention time

a See Analytical SOP References table (Table F-5).

January 2022

B-39

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Table B-9: Data Verification and Validation (Steps I and Ila/IIb) Process

Data Review Input

Description

Responsible for
Verification
(name, organization)

Step I/IIa/IIba

Internal/External

Laboratory system audits

Determine whether the laboratory holds a
current DoD ELAP certification for all
analyses to be performed for the project.

Project Chemist
(Navy consultant)

Step I

Internal

Field procedures

Determine whether field procedures are
performed in accordance with this SAP and
prescribed procedures.

QA Program Manager
(Navy consultant)

Step I

Internal

Field logbook and notes

Review the field logbook and any field
notes on a weekly basis and place them in
the project file.

Copies of the field logbook and field notes
will be provided to the Navy consultant
CTO manager and included in the Field
Audit Report.

Field Manager
(Navy consultant)

Step I

Internal

Instrument calibration sheets

Determine whether instruments are
calibrated and used in accordance with
manufacturer's' requirements.

Project Chemist
(Navy consultant) &
Data Validator
(LDC)

Step I

Internal & External

CoC forms

Review CoC completed forms and verify
them against the corresponding packed
sample coolers.

A copy of each CoC will be placed in the
project file. The original CoC will be taped
inside the cooler for shipment to the
analytical laboratory.

Project Chemist
(Navy consultant)

Step I

Internal

Sampling analytical data
package

Verify all analytical data packages for
completeness prior to submittal of the data
to the data validator.

Laboratory Project

Manager

(APPL)

Step I

External

Analytes

Determine whether all analytes specified in
Table F-2 were analyzed and reported on
by the laboratory.

Project Chemist
(Navy consultant)

Step Ha

Internal

B-40

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix B	

Data Review Input

Description

Responsible for
Verification
(name, organization)

Step I/IIa/IIba

Internal/External

CoC and field QC logbook

Examine data traceability from sample
collection to project data generation.

Project Chemist
(Navy consultant)

Step Ha

Internal

Laboratory data and SAP
requirements

Assess and document the performance of
the analytical process.

A summary of all QC samples and results
will be verified for measurement
performance criteria and completeness.
Full Validation will be performed on 10%
of the data and Standard Validation will be
performed on 90% of the data. A report
will be prepared within 21 days of receipt.

Data Validator
(LDC) &

Project Chemist
(Navy consultant)

Steps IIa& lib

Internal & External

VOCs

Complete Procedure II-B, Level C and
Level D Data Validation Procedure for
GC/MS Volatile Organics by SW-846
8260B (DON 2015).

Data Validator
(LDC)

Step Ha

External

PAHs and SVOCs

Complete Procedure II-C, Level C and
Level D data Validation Procedure for
GC/MS Semivolatile Organics by SW-846
8270C (Full Scan and SIM) (DON 2015).

Data Validator
(LDC)

Step Ha

External

TPH

Complete Procedure II-H, Level C and
Level D Data Validation Procedure for
Extractable Total Petroleum Hydrocarbons
by SW-846 8015B (DON 2015).

Data Validator
(LDC)

Step Ha

External

Sampling plan

Determine whether the number and type of
samples specified in Table F-l were
collected and analyzed.

Project Chemist
(Navy consultant) &
Field Manager
(Navy consultant)

Step lib

Internal

Field QC samples

Establish that the number of QC samples
specified in Table F-l were collected and
analyzed.

Project Chemist
(Navy consultant)

Step lib

Internal

B-41

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01

Appendix B	

January 2022

Data Review Input

Description

Responsible for
Verification
(name, organization)

Step I/IIa/IIba

Internal/External

Project quantitation limits and
data qualifiers

Establish that sample results met the
project quantitation limits and qualify the
data in accordance with Procedure II-A,

Data Validation Procedure (DON 2015).

Data Validator
(LDC) &

Project Chemist
(Navy consultant)

Step lib

Internal & External

Validation report

Summarize outcome of data comparison to
MPC in the SAP. Include qualified data
and an explanation of all data qualifiers.

Data Validator
(LDC)

Step Ha

External

MPC measurement performance criteria

a Ha	Compliance with methods, procedures, and contracts. See Table 10, page 117, UFP-QAPP manual, V. 1 (DoD 2005).

lib	Comparison with measurement performance criteria in the SAP. See Table 11, page 118, UFP-QAPP manual, V. 1 (DoD 2005).

B-42

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix C	

Appendix C - Standard Operating Procedures

(DON 2015)

-------
Site Characterization Plan

November2021 Release, U.S. Navy Well 2254-01 January 2022
Appendix C	

This page intentionally left blank

-------
I. Field Procedures

Procedure I-A Planning

Procedure I-A-l Development of Project Quality Objectives
Procedure I-A-5 Utility Clearance

Procedure I-A-6 Investigation-Derived Waste Management
Procedure I-A-8 Sample Naming

Procedure I-B Sampling

Procedure I-B-l Soil Sampling
Procedure I-B-2 Geophysical Testing
Procedure I-B-5 Surface Water Sampling

Procedure I-C Well Construction and Well Development

Procedure I-C-l Monitoring Well Installation and Abandonment
Procedure I-C-2 Monitoring Well Development

Procedure I-D Miscellaneous Sampling
Procedure I-D-l Drum Sampling

Procedure I-E Soil and Rock Classification

Procedure I-F Equipment Decontamination

Procedure I-I Land Surveying

II.	Data Validation Procedures

Procedure II-A Data Validation

III.	QC Procedures

Procedure III-A Laboratory QC Samples (Water, Soil)

Procedure III-B Field QC Samples (Water, Soil)

Procedure III-D Logbooks

Procedure III-E Record Keeping, Sample Labeling, and Chain-of-Custody
Procedure III-F Sample Handling, Storage, and Shipping

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program

Procedure Number:

l-A-1

Development of Project Quality Objectives

Revision Date:

May 2015



Page:

1 Of 17

Development of Project Quality

Objectives



1.	Purpose

This standard operating procedure establishes standard guidelines for the United States (U.S.) Navy
Environmental Restoration (ER) Program, Naval Facilities Engineering Command (NAVFAC),
Pacific personnel for the development of project quality objectives (PQOs) for a contract task order
(CTO). These procedures will help ensure that CTOs meet the purpose and objectives of the task
order, as well as the necessary documentation of the environmental decisions that need to be made
and the level of data quality needed to ensure that those decisions are based on sound scientific data.
The PQOs will be used to develop the work plan (WP), which provides the detailed project-specific
objectives, specifications, and procedures needed to conduct a successful data collection activity.
Data will be collected according to specifications set forth in the WP, and a data quality assessment
will be performed to determine whether PQOs have been satisfied.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program. As
professional guidance for specific activities, this procedure is not intended to obviate the need for
professional judgment during unforeseen circumstances. Deviations from this procedure while
planning or executing planned activities must be approved and documented by the following prime
contractor representatives: the CTO Manager and the Quality Assurance (QA) Manager or Technical
Director. A Navy project representative (i.e., Remedial Project Manager or QA Manager) shall also
concur with any deviations.

3.	Definitions

3.1	Applicable or Relevant and Appropriate Requirements (ARARS)

ARARs include cleanup or control standards, regulatory requirements, or limitations promulgated
under federal or state environmental laws that specifically address a hazardous substance, pollutant,
contaminant, remedial action, location, or other circumstance that applies to a particular CTO.

3.2	Analytes

Analytes are contaminants that might be present at a site as well as other chemical and physical
properties for which the laboratory will analyze samples.

3.3	Analytical Methods

Analytical methods are standardized procedures used to identify and quantify analytes in
environmental samples.

3.4	PQOs

PQOs are qualitative and quantitative statements derived from a systematic planning process (e.g.,
U.S. Environmental Protection Agency [EPA] Guidance on Systematic Planning Using the Data

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
2 of 17

Quality Objectives Process (EPA 2006) that clarify study objectives, define the appropriate type of
data, and specify tolerable levels of potential decision errors. PQOs will be used as the basis for
establishing the quality and quantity of data needed to support decisions.

3.5	PQO Process

The PQO process is a systematic planning tool based on the scientific method for establishing
criteria for data quality and for developing a data collection design.

3.6	Action Level

Action levels (ALs) are analyte concentrations that if exceeded in site media, indicate that some
action is needed to address hazards associated with onsite contamination.

4.	Responsibilities

The prime contractor CTO Manager is responsible for ensuring that development of PQOs is
performed in compliance with this procedure and for identifying instances of noncompliance. The
CTO Manager is responsible for ensuring that all personnel involved in sampling and/or testing shall
have the appropriate education, experience, and training to perform their assigned tasks as specified
in Chief of Naval Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

5.	Procedures

PQOs shall be developed following performance of the site reconnaissance and prior to development
of the WP for all CTOs. When critical environmental decisions need to be made,(e.g., final decision-
making or compliance with a standard), the project team should follow a formal systematic planning
process such as the data quality objectives (DQO) process described in the Guidance on Systematic
Planning Using the Data Quality Objectives Process, EPA QA/G-4 (EPA 2006). The formal DQO
process as described in EPA QA/G-4 requires statistical expertise to define the amount of error
acceptable when making an environmental decision and includes the following seven steps:

1.	State the problem.

2.	Identify the goals of the study.

3.	Identify information inputs.

4.	Define the study boundaries.

5.	Develop the analytic approach.

6.	Specify performance or acceptance criteria.

7.	Develop the plan for obtaining data.

Graded Approach

For data collection activities that are either exploratory or small in nature, or where specific
decisions cannot be identified, the formal process is not necessary. For these projects, the project

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
3 of 17

team should use an abbreviated systematic planning process (e.g., Steps 1-4) to help identify the
PQOs and action limits, and to select appropriate sampling, analytical and assessment activities.

Incremental Sampling Approach

Incremental sampling methodology (ISM) is such an integral part of environmental investigations in
Hawaii, and therefore, a discussion of ISM PQOs is necessary. The State Department of Health
strongly encourages the use of incremental sampling (IS) to enhance the sample representativeness
during environmental investigations when appropriate (DOH 2009). IS is a structured sampling
protocol that enhances sample representativeness and reduces data variability in the investigation of
contaminated soil. The objective of IS is to obtain a single sample for analysis that has an analyte
concentration representative of a decision unit within the error limitations required for the project. IS
improves the reliability and defensibility of sampling data by reducing variability when compared to
conventional discrete sampling strategies. An IS approach requires site-specific information to be
considered during the planning process. Therefore, the steps necessary to complete the DQO process
as they apply to investigations where IS is used is detailed in Attachment I-A-l-1.

5.1 Step 1: State the Problem

The first step of the PQO process is to state the problem. Clearly define the problem once it has been
identified. Assemble a planning team to completely assess the problem. Designate one member of
the planning team as the primary decision maker. The planning team shall compile and evaluate
available information to develop a concise description of the problem and a conceptual site model
(CSM). The CSM describes exposure pathways and exposure scenarios, facilitates identification of
decisions that must be made, and identifies deficiencies in the existing information. Prepare a brief
summary of the problem once these have been identified.

5.1.1 Identify Members of the Planning Team

The members of the planning team shall be appropriate for the size and complexity of the problem.
PQO development requires that the data users be involved in the planning of CTO activities. Because
of the interdisciplinary nature of activities, it is important to obtain the appropriate technical
expertise in developing PQOs. Data users normally consist of the primary decision maker, and
primary and secondary data users.

Primary data users generally consist of those individuals involved in the ongoing CTO activities. The
CTO Manager must identify those technical staff needed for the project and involve them in the
planning process. For example, if groundwater contamination is a concern, hydrogeologists must be
involved. Persons with expertise in analytical chemistry must be involved to specify the type of
analyses that may be used and the limitations of these analyses. Toxicologists or others familiar with
risk assessment must also be involved to ensure that migration and exposure pathways, potential
receptors, and contaminants and levels of concern are considered.

Secondary data users are those that use data to support their activities. These include Navy
personnel, and state and federal regulatory enforcement agencies. The roles and responsibilities shall
be determined for each member of the planning team. The objectives of the team are to develop a
concise description of the problem, specify resources that are available, and determine deadlines for
the study.

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
4 Of 17

5.1.2	Identify the Primary Decision Makers

Identify the primary decision makers for the planning team. These individuals have the ultimate
authority for making final decisions based on recommendations from the planning team. Examples
of primary decision makers are the Navy personnel who must determine what the site will ultimately
be used for and the project manager who determines how the investigation should be conducted to
meet the investigation objectives.

5.1.3	Develop a Concise Description of the Problem

The planning team shall prepare a brief summary that concisely describes the problem and the
conditions or circumstances that are causing the problem. This summary should be based on a site
reconnaissance, and a review of site history and potential sources of contamination.
Procedure Number I-A-4, Site Reconnaissance provides the procedures for conducting a site
reconnaissance. Review literature and studies to ensure that the problem is correctly defined and has
not been previously solved. Information regarding site history and potential sources of contamination
can be obtained from previous studies and investigations.

The CSM may be helpful in developing a description of the problem. The Department of the Navy
Environmental Restoration Program manual (DON 2006) and Guidance for Conducting Remedial
Investigations and Feasibility Studies under CERCLA (EPA 1988) provide a general discussion
about the development and use of the CSM. Additional CSM tools are available through the navy's
Environmental Restoration Technology Transfer Tool (DON 2010). If a CSM already exists, it may
need to be refined. A CSM describes the site and its surroundings, potentially complete and complete
exposure pathways for the particular media for both human and ecological receptors, and exposure
pathways. It also presents hypotheses regarding the contaminants present, their routes of migration,
and their potential site impact. The hypotheses are tested, refined, and modified through the WP
activities, which shall be referenced by the CSM.

The areas to be assessed during development of the CSM include the following:

•	Population, environmental, and welfare concerns

•	Potential exposure routes and contaminant transport pathways

•	Nature and extent of contamination at the site

•	Extent to which the contamination has been defined and can be defined in the future

•	Potential for migration from the site (if known)

•	Extent to which site contamination levels have exceeded ARARs or other related
environmental or public health standards or criteria (if known)

A complex problem may require division into separate studies.

5.1.4	Specify Available Resources and Relevant Study Deadlines

Specify the budget, personnel, and projected deadline in the summary. Discuss time constraints, such
as base closures, if appropriate.

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number: i-A-1
Revision Date: May 2015
Page:	5 of 17

5.2 Step 2: Identify the Goals of the Study

The second step of the PQO process is to identify the goals of the study. Identify relationships
between this decision and any other current or subsequent decisions.

5.2.1	Identify the Principal Study Question

Identify a principal study question based on the problem. The principal study question focuses on
pertinent information that is necessary to resolve the problem. State the principal study question as
specifically as possible. In general, the question is whether the site poses a threat to human health
and/or the environment. Specific examples are as follows:

•	Does the contaminant concentration in groundwater exceed acceptable levels?

•	Does the pollutant concentration exceed the National Ambient Air Quality Standard?

•	Does a contaminant pose a human health or ecological risk?

•	Is the contaminant concentration significantly above background levels (suggesting a
release)?

5.2.2	Define Alternative Actions that Could Result from Resolution of the Principal Study
Question

Possible answers to the study question could result in one or more alternative actions including no
action. The following example illustrates how alternative actions are defined based on possible
answers to the principal study question: "Does a contaminant pose a human health or ecological
risk?" If the answer is yes, alternative actions could be site remediation through removal of
contaminated soil, contaminant removal through a soil vapor extraction system, or bioremediation. A
quarterly groundwater program may also be implemented to monitor the effect of the site
contamination on groundwater. If the answer is no, then the site investigation will go to No Further
Response Action Planned.

5.2.3	Combine the Principal Study Question and Alternative Actions into a Decision
Statement

Create a decision statement by combining the principal study question with alternative actions. The
format may be as follows: "Determine whether or not [unknown environmental
conditions/issues/criteria from the principal study question] require (or support) [taking alternative
actions]." Using the example above, the decision statement could be "Determine whether or not
volatile organic constituent contamination from the site poses a risk to groundwater and requires
quarterly groundwater sampling. If the answer is no, then no further action is required."

5.2.4	Organize Multiple Decisions

If multiple decision statements are necessary to resolve the problem, they should be organized and
prioritized. Describe the decision-making process, taking into account how the data from a previous
phase will affect the following phase. Implement a phased approach to sampling if relationships exist
between this decision and other current or subsequent decisions. A flowchart or diagram may be
helpful.

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
6 Of 17

5.3 Step 3: Identify Information Inputs

The third step of the PQO process is to identify the information needed and sources for each
information input. Determine contaminant-specific ALs, sampling techniques, and analytical
methods during this step.

5.3.1	Identify the Information Required To Resolve the Decision Statement

Collect various types of information in order to resolve the decision statement. Information types
include data uses and types of data. Data uses can be described in terms of general categories, which
include the following:

•	Identification of the presence or absence of contamination at a site

•	Site characterization (delineation of the nature and extent of contamination)

•	Assessment of immediate public health or worker health and safety concerns for site
investigation activities

•	Completion of a risk assessment

•	Evaluation and design of remedial action alternatives

Acquire information using either a monitoring or modeling approach, or a combination of both. Use
this information with existing site information and the CSM to determine what type of data is
required to meet the CTO objective. Data types generally consist of types of samples that need to be
collected (soil, groundwater, aquifer hydraulic conductivity, and geotechnical), as well as sample
analytes. Refer to Procedure Number I-A-2, Selection of Analytes, for procedures on selection of
sample analytes.

5.3.2	Determine Sources for Each Informational Input

Identify and qualitatively evaluate for appropriateness the sources for each informational input.
Information input sources include previous investigative results, historical records, regulatory
guidance, professional judgment, or scientific literature. List those inputs that are obtained through
environmental measurements.

5.3.3	Determine the Necessary Information for Establishing Action Levels

Determine the basis for establishing contaminant-specific ALs. The AL is the threshold value that
provides the criterion for selecting an alternative action. Derive contaminant-specific action levels
from regulatory thresholds or standards, technology based limits, or exposure assessment analysis.

ALs directly affect data quality requirements, in that the analytical methods chosen must have
reporting limits that are well below the AL. Reporting limits depend upon the parameter and
analytical method being considered.

5.3.4	Identify Potential Sampling Techniques and Appropriate Analytical Methods

Identify potential sampling techniques and appropriate analytical methods for environmental
measurements that were previously listed. Use the Project Procedures Manual as the protocol for
sampling, and identify significant deviations. Determine the detection limit, limit of detection, and
limit of quantitation for each analytical method.

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
7 of 17

5.4 Step 4: Define the Study Boundaries

The fourth step of the PQO process is to define the spatial boundaries of the study and the temporal
boundaries of the decision. The boundaries ensure that the data collection design incorporates the
time periods during which the study shall be implemented, populations and geographic areas that
shall be sampled, and the applicable time period. The study area may be stratified into
subpopulations in order to reduce the complexity of the problem. The spatial boundaries or
geographical region of the general study area may expand or contract with each phase of sampling
and may include focused areas of sampling or hot spots. Define practical constraints on data
collection during this step.

5.4.1	Specify the Characteristics that Define the Population of Interest

Specify the characteristics that define the population of interest. For example, Aroclor-1260 is more
specific than polychlorinated biphenyls (PCBs), and adult construction worker receptor is more
specific than human receptor.

5.4.2	Define the Geographic Area Applicable to the Decision(s)

Define the geographic area that is applicable to the decision. The property boundary, depth below
ground surface, or natural habitat range for a particular animal species may define a specific
geographic area.

5.4.3	Divide the Population into Strata with Relatively Homogeneous Characteristics

The population of the study area may be stratified into subpopulations with relatively homogeneous
characteristics in order to reduce the complexity of the problem. Examples of characteristics include
specific contaminants, age, and species type.

5.4.4	Determine the Decision Timeframe

Determine the timeframe to which the decision applies. Define time frames for the overall population
and for any subpopulation of interest; then address discrepancies that may arise from the short time
frame of data collection relative to the long time periods for implementing decisions.

5.4.5	Determine When to Collect Data

Determine the data collection time based upon the most favorable conditions. These conditions
include weather, temperature, humidity, wind, or amount of sunlight. For example, a quarterly
groundwater monitoring program could be implemented because seasonal changes could affect
groundwater concentrations.

5.4.6	Determine the Scale of Decision Making

Determine the most appropriate scale of decision-making based on the spatial or temporal
boundaries. For example, in a study where the decision statement is, "Determine whether volatile
organic constituent contamination from the site is a risk to groundwater and requires quarterly
groundwater monitoring," the geographic area is the site boundary, and the population is benzene,
toluene, ethyl benzene, and xylene (BTEX). The scale of decision-making could be set to a particular
chemical that is associated with BTEX, such as benzene, which is a known carcinogen. A scale of
decision-making based on temporal boundaries could specify the time between groundwater
sampling events.

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
8 of 17

5.4.7 Identify Practical Constraints on Data Collection

Identify practical constraints that could potentially interfere with data collection, such as seasonal or
meteorological conditions, access to property or buildings, time, or unavailable personnel.

5.5 Step 5: Develop the Analytic Approach

The fifth step of the PQO process is to develop the analytic approach. This procedure involves
identifying the statistical parameter that characterizes the population of interest, specifying the ALs
for the decision, and combining the outputs from the previous PQO steps in order to develop
decision rules.

5.5.1	Specify the Statistical Parameter of the Population of Interest

Specify statistical parameters that characterize the population or parameter of interest. The parameter
may be the mean, median, or percentile that will be used by the decision maker. Statistical
parameters may be specified by the regulatory agency or the risk assessment analysis.

Using the mean as the statistical parameter is useful when the AL is based on long-term, average
health effects, when the population is uniform, and generally requires fewer samples than the other
statistical parameters. However, this may not be a representative measure for highly skewed
populations or populations that contain a large number of nondetect measurements.

Using the median as the statistical parameter is useful when the AL is based on long-term, average
health effects, is more representative than the mean when the population is skewed or contains a
large number of nondetect measurements, and relies on few statistical assumptions. However, this
approach may be impacted by extreme values and is still not a representative measure for highly
skewed populations.

Using the upper proportion or percentile statistical parameter is useful for protection against extreme
health effects, provides the best control of extreme values for highly variable populations, is useful
for skewed distributions, may be appropriate for populations that contain a large number of
nondetect measurements (provided the detection limit is less than the AL), and relies on few
statistical assumptions. However, this approach requires larger sample sizes than the mean statistical
parameter.

5.5.2	Specify the Action Level for the Study

The decision maker shall specify the AL for the study. For example, if the trichloroethene (TCE)
concentration in groundwater samples exceeds the drinking water criteria of 5 micrograms per liter
(|_ig/L). a particular action may be specified. If TCE is detectable at levels below 5 (ig/L, another
action may be specified. Specify the procedure for establishing background levels in this step.

5.5.3	Combine Outputs from the Previous PQO Steps into a Decision Rule

Incorporate the parameter of interest and action levels into a decision rule or an "if...then..."
statement. If a parameter of interest exceeds a specified AL, then an alternative action will result. For
example, if the concentration of TCE in groundwater samples exceeds 5 (ig/L, then the production
well that distributes this groundwater to the population for consumption will be shut off. If the
production well is shut off due to elevated TCE concentrations, then remediation of groundwater
may be necessary using a water treatment system.

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
9 of 17

5.6 Step 6: Specify Performance or Acceptance Criteria

When required by the project objectives, the sixth step is to specify performance or acceptance
criteria. This step involves determining the possible range of the parameter of interest, defining the
potential consequences of both types of decision errors, specifying a range of minor consequences
for decision errors, assigning probability values to reflect the acceptable probability for decision
errors to occur, and ensuring that decision errors accurately reflect consequences.

5.6.1	Determine the Possible Range of the Parameter of Interest

Determine the possible range of the parameter of interest by establishing upper and lower boundaries
or control limits. Historical data may be used to establish the range of the parameter of interest. For
example, the mean concentration of TCE may be between 0.5 and 10 (ig/L based on quarterly
groundwater sampling results. Only the range of parameters that are expected to drive risk is defined.
In some instances, this will not be known and should be so stated.

5.6.2	Define the Potential Consequences of Decision Errors

Environmental sample data has inherent uncertainty associated with it. The uncertainty can be
described in terms of sampling design error and measurement error. Sample design error is
associated with both random and systematic errors at different stages of the sample acquisition.

Sampling design error arises when sampling plans don't allow for complete variability of the site,
thus not allowing an appropriate decision to be made for the site. This type of error can result in data
variability or imprecision (random error) and bias data (systematic error).

Measurement error is variability resulting from imperfections in the measurement and analysis
system. This type of error is introduced during sample collection, handling, preparation, and
analysis. Other contributors to measurement error include data reduction, transmission, and storage.

Sampling design error together with measurement error is defined as "total study error" or "total
variability." It is necessary to manage the total study error by rigorous evaluation of the sample
design and measurement systems to control decision errors to acceptable levels.

Perform the management of decision error through the use of hypothesis testing. Hypothesis testing
requires that a baseline condition (i.e., contaminants are below the AL) and an alternative condition
(i.e., contaminants exceed the AL) be defined. This test can be used to show that there is insufficient
evidence to indicate that the baseline condition is false (acceptance that the baseline condition is
true), or that the baseline condition is probably false (acceptance that the alternative condition is
true). This process places the burden of proof on rejecting the baseline condition unless there is
substantial evidence that the baseline condition is not true.

The two types of decision errors are false rejection errors and false acceptance errors. A false
rejection error occurs when the limited amount of sample data leads to the belief that the baseline
condition is probably false when it is really true. A false acceptance error occurs when the data leads
to the belief that the baseline condition is true when it is really false. Define the false rejection and
false acceptance errors for each decision rule and describe the potential consequences of each. For
example, the baseline condition could be that a particular site has PCB contamination below AL; a
false rejection error (of the baseline condition) could occur when PCB concentrations are determined
to be above the AL, when the true PCB concentrations are below the AL. A false acceptance error

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
10 of 17

(of the baseline condition) could occur when the PCB concentrations are determined to be below the
AL when the true PCB concentrations are above the AL. Define and evaluate the potential
consequences of each of these in terms such as human health and ecological risks, economic and
social costs, and political and legal ramifications.

Decision errors can never be completely eliminated from environmental investigations but they can
be managed. Careful evaluation of the sampling design and measurement methods will help ensure
an adequate number of samples are collected utilizing the appropriate protocol and analyzing with
the appropriate technique.

A comprehensive discussion of decision errors can be found in Section 6 Specify Tolerable Limits
on Decision Errors in Guidance on Systematic Planning Using the Data Quality Objectives Process.
EPA QA/G-4. (EPA 2006).

5.6.3	Specify a Range of Minor Consequences for Decision Errors

Specify a broad range of minor consequences or a gray region for decision errors when statistical
sampling is used. The gray region is a range of possible parameter values where the consequences of
false rejection or acceptance decision errors are relatively minor.

5.6.4	Assign Limits to Reflect the Acceptable Probability for Decision Errors to Occur

For statistical sampling, assign probability values to points above and below the gray region that
reflect the decision maker's tolerable limits for making an incorrect decision. At a minimum, the
decision maker shall specify a false rejection decision error limit at the AL and a false acceptance
decision error limit at the lower end of the gray range. Aggressive identification of reasonably high
levels of error is recommended because the risk assessment procedures are relatively conservative.

5.6.5	Ensure that Decision Errors Accurately Reflect Consequences

For statistical sampling programs, check the limits on decision errors to ensure that they accurately
reflect the relative consequences for each type of decision error.

5.7 Step 7: Develop the Plan for Obtaining Data

When required by the project objectives, the seventh step of the PQO process is to develop the plan
for obtaining data. This procedure involves reviewing the PQO outputs and existing environmental
data, developing general sampling and analysis design alternatives, verifying that PQOs are achieved
for each design, selecting the most re source-effective design that satisfies all of the PQOs, and
documenting the details and assumptions in the sampling and analysis plan.

5.7.1	Review PQO Outputs and Existing Environmental Data

Review the PQO outputs from the previous steps for internal consistency. Also review existing data
and identify data significant to the design.

5.7.2	Develop General Sampling and Analysis Design Alternatives

Develop general sampling and analysis design alternatives based on the PQO outputs and other
relevant information. These alternatives shall be cost effective and balance the sample size and
measurement performance with the sample collection techniques and analytical methods available.
Factors to be considered in this step include the phase, media, sample type, number of samples,

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number: i-A-1
Revision Date: May 2015
Page:	11 of 17

sampling locations, analytical methods, and QA/quality control requirements. Also develop a
schedule for all sampling activities. The output of this process is a well-defined WP.

For nonstatistical sampling programs, present a justification for using purposive sampling, as well as
identification and rationale for using a phased approach and other sampling strategies that are
somewhat unusual. Discuss alternative analytical and field sampling strategies and provide rationales
for using them. Develop and describe several different sampling scenarios for statistically based
plans.

5.7.3	Verify that PQOs Are Achieved for Each Design

Briefly show that the sampling design will achieve the PQOs. For statistically based plans, define a
method for testing the hypothesis and a corresponding sample size formula (e.g., T-test), develop a
statistical model that describes the relationship between the measured value and the true value, and
develop a cost function that relates the number of samples to the total cost of sampling and analysis.

5.7.4	Select the Most Resource-Effective Design that Satisfies all of the PQOs

Evaluate each design option in order to select the most resource-effective and/or cost-effective
design that satisfies all of the PQOs.

5.7.5	Document Details and Assumptions in the Work Plan

Document the operational details and theoretical assumptions of the selected design in the WP.

6.	Records

None.

7.	References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

Department of the Navy (DON). 2006. Department of the Navy Environmental Restoration Program
Manual. Alexandria, VA: Naval Facilities Engineering Command. August.

	2014. Environmental Readiness Program Manual. OPNAV Instruction 5090. ID. 10 January.

Environmental Protection Agency, United States (EPA). 1988. Guidance for Conducting Remedial
Investigations and Feasibility Studies Under CERCLA. Interim Final. EPA/540/G-89/004. Office
of Emergency and Remedial Response. October.

	2006. Guidance on Systematic Planning Using the Data Quality Objectives Process. EPA

QA/G-4. EPA/240/B-06/001. Office of Environmental Information. February.

Naval Facilities Engineering Command (NAVFAC). 2010. NAVFAC Technology Transfer (T2)
Program.

-------
NAVFAC Pacific ER Program

Development of Project Quality Objectives

Procedure Number: i-A-1
Revision Date: May 2015
Page:	12 of 17

Procedure I-A-2, Selection of Analytes.

Procedure I-A-4, Site Reconnaissance.

8. Attachments

Attachment I-A-l-1: DQO Process Using IS Approach

-------
Attachment l-A-1-1
DQO Process Using IS Approach

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
15 of 17

The State of Hawaii, Department of Health, Hazard Evaluation and Emergency Response Office
strongly encourages the use of incremental sampling (IS) to enhance sample representativeness in the
investigation of contaminated soil (DOH 2009). IS is a structured composite sampling and
processing protocol that reduces data variability and provides a reasonably unbiased estimate of
mean contaminant concentrations in a volume of soil targeted for sampling. IS provides
representative samples of specific soil volumes defined as decision units (DUs) by collecting
numerous increments of soil (typically 30-100 increments) that are combined, processed, and
subsampled according to specific protocols (DOH 2009 and ITRC 2012).

Similar to other sampling designs, systematic planning must be conducted and used to develop the
scope of the investigation. The following subsections detail the steps needed to complete the data
quality objective (DQO) process (EPA 2006) as they apply to IS investigations.

1.	Define the problem that is prompting the investigation. This step should include:

-	A description of the problem

-	Development of a conceptual site model for the issue being investigated

-	Identification of the types of data needed along with alternative approaches

-	Identification of planning team members

-	A schedule, including constraints and deadlines, for the project

2.	Identify the goals of the investigation. This step should include identification of the principle
study questions (PSQs) and alternative outcomes for each PSQ. Decision statements can then
be written based on the PSQs and various outcomes.

3.	Identify what information is needed to address the problem statement and associated PSQs.
This should include the environmental parameters or characteristics (i.e., data) that will be
needed to answer the questions being asked at a site. The data could be historical or it could
be that new, better, or additional data is needed. This should be identified in the sampling
plan. Details of the specific data may include, but are not limited to the following:

-	Chemical parameters

-	Physical parameters

-	How many DUs

-	What size DUs are needed

-	How many replicate samples are needed

-	How many increments per sample are necessary (Anything less than 30 increments
should have a full justification)

Also included in this section is the type of data needed to meet the performance criteria for
the site. The number and location of DUs proposed for field replicate sampling and the
number of replicates for those DUs must be included. In addition to the field replicates, it
must be determined whether laboratory replicates should be collected on the project.
Laboratory replicates are used to determine the source of sampling error (i.e., field or
laboratory) once your data is received from the laboratory.

-------
NAVFAC Pacific ER Program
Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
16 of 17

4.	Define the boundaries of the investigation. There is typically a spatial and temporal
boundary for the investigation. This is where the target population of interest is identified
which informs the size and thickness of the DUs, which is identified here. Also included in
this section is the smallest unit on which decisions will be made. This is normally equal to
the size of your DUs. Lastly, factors or site features that restrict the ability to collect all the
data specified in step three above, should be identified here. These are usually access
limitations, either physical or legal.

5.	This section should introduce the decision rules for the investigation. These are comprised of
a series of "if... then" statements. These if/then statements will be generated using the action
level or screening criteria selected for the project and identified in your Uniform Federal
Policy for Quality Assurance Project Plans Sampling and Analysis Plan (SAP).

6.	This step should specify the acceptance criteria for the study. Acceptance criteria will
typically be based on an evaluation of the total study error, which includes the field sampling
error and the total laboratory error. The total study error is measured using the relative
standard deviation (RSD) of the field replicates. The acceptance criterion should be an RSD
less than or equal to 35 percent RSD. If the data do not meet this criterion, they will have to
be evaluated further by the project stakeholders to decide whether the DQOs have been met.
One factor for evaluating the data is whether the result is within an order of magnitude of the
screening level. Data more than an order of magnitude from the screening level are unlikely
to be affected sufficiently to prevent a good decision from being made. Another method to
assist stakeholders with data that don't meet the acceptance criterion is to calculate a 95
percent upper confidence limit (UCL). Use of the 95 percent UCL rather than the laboratory
reported value will give an additional level of confidence to decision makers that the
reported values are protective of the receptors. In addition to the acceptance criterion, the
detection limit, limit of detection, and limit of quantitation for the various analytes needed to
achieve the performance objectives for the project should be provided in Worksheet #15 of

7. The last step must include a compilation of all the information generated in the first six
steps. This information should then be used to identify alternative sampling and analysis
designs that meet the project objectives. This section should lay out how the samples will be
collected, the size, shape, and depth of the DUs, reference to the sampling procedures that
will be followed, the sampling instruments that will be used as well as the laboratory
containers that will be used to send samples to the laboratory for analysis. Also, reference to
the laboratory processing and sub-sampling procedures should be documented in this
section. If the soil type at the site is unknown, it is recommended that at least one backup
type of sampling tool be kept available in case the primary tool proves unusable for some
reason. For instance, if the SAP called for a hand tool (e.g., slide hammer driven soil corer)
and the soil turns out to be very hard, the project team should have a backup method to
collect the increments such as some kind of power tool or direct push rig.

DU size, depth, and location will determine whether the data is able to satisfy your project
objectives. It is imperative that your DUs are suitable for achieving these project objectives.

the SAP.

Things to consider when deciding DU size:

-------
NAVFAC Pacific ER Program
Development of Project Quality Objectives

Procedure Number:
Revision Date:
Page:

l-A-1
May 2015
17 of 17

•	If you need to make a decision about whether unrestricted use is appropriate for a site, then
the DUs should be no larger than 5,000 square feet (default residential lot in Hawaii) unless
regulators and Navy agree it can be larger.

•	If commercial/industrial use is intended, then DUs can be larger than 5,000 square feet. The
size of DUs should be agreed upon by project stakeholders upfront in the planning phase
(e.g., SAP or work plan). Also, any land use other than unrestricted use will require LUCs on
the property.

•	Depending on the needs or goals of the investigation, DUs can be reduced in size to
whatever is needed (e.g. DUs for remediation or confirmation sampling).

•	Involve a risk assessor if risk assessment is planned with the data. You will need to
determine what receptors and pathways will be evaluated in the risk assessment and the data
must be able to satisfy those objectives. Risk assessment needs will often impact the size,
location, and depth of your DUs.

Things to consider when deciding where to place DUs (Many of these same criteria should also be

used to determine which DUs should have replicate samples collected, when less than 100 percent of

the DUs will have replicate samples collected):

•	Evaluate historical land use.

•	Evaluate site features such as geology to identify different soil types or possible transport
mechanisms.

•	Identify potential source areas (current and past).

•	Evaluate fate and transport properties of the chemicals of potential concern.

•	Evaluate existing sampling data from the site.

•	Consult a risk assessor if the data will be used in a risk assessment. Again, receptors and
pathways must be evaluated to ensure the DUs will provide data to meet the risk assessment
and project objectives. Risk assessors can also provide input on which DUs and how many
should have replicate samples collected.

•	Evaluate site access restrictions due to current site use that could affect where DUs are
placed.

References

Department of Health, State of Hawaii (DOH). 2009. Technical Guidance Manual for the

Implementation of the Hawaii State Contingency Plan. Interim Final. Honolulu: Office of Hazard
Evaluation and Emergency Response. 21 June, http://www.hawaiidoh.org/tgm.aspx.

Environmental Protection Agency, United States (EPA). 2006. Guidance on Systematic Planning
Using the Data Quality Objectives Process. EPA QA/G-4. EPA/240/B-06/001. Office of
Environmental Information. February.

Interstate Technology and Regulatory Council (ITRC). 2012. Incremental Sampling Methodology.
February.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program

Procedure Number:

l-A-5

Utility Clearance

Revision Date:

May 2015



Page:

1 of 5

Utility Clearance

1.	Purpose

This standard operating procedure describes the process for determining the presence of subsurface
utilities and other cultural features at locations where planned site activities involve the physical
disturbance of subsurface materials. The procedure applies to the following activities: soil gas
surveying, excavating, trenching, drilling of borings and installation of monitoring and extraction
wells, use of soil recovery or slide-hammer hand augers, and all other intrusive sampling activities.
The primary purpose of the procedure is to minimize the potential for damage to underground
utilities and other subsurface features, which could result in physical injury, disruption of utility
service, or disturbance of other subsurface cultural features.

2.	Scope

This procedure applies to all United States Navy Environmental Restoration (ER) Program projects
performed in the Naval Facilities Engineering Command, Pacific Area of Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the Uniform Federal Policy-Quality Assurance Project Plan
(DoD 2005). As professional guidance for specific activities, this procedure is not intended to
obviate the need for professional judgment during unforeseen circumstances. Deviations from this
procedure while planning or executing planned activities must be approved and documented by the
following prime contractor representatives: the CTO Manager and the Quality Assurance (QA)
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

3.	Definitions

3.1	Utility

For this procedure, a utility is defined as a manmade underground line or conduit, cable, pipe, vault
or tank that is, or was, used for the transmission of material or energy (e.g., gas, electrical, telephone,
steam, water or sewage, product transfer lines, or underground storage tanks).

3.2	As-Built Plans

As-built plans are plans or blueprints depicting the locations of structures and associated utilities on a
property.

3.3	One-Call

The Utility Notification Center is the one-call agency for Oregon, Washington, Montana, and
Hawaii. The Utility Notification Center is open 24 hours a day, and accepts calls from anyone
planning to dig in. The phone number for the Hawaii One Call Center is 1-866-423-7287 (or 811).
Additional information can be found at http://www.callbeforeyoudig.org/hawaii/index.asp.

Calling before you dig ensures that any publicly owned underground lines will be marked, so that
you can dig around them safely. Having the utility lines marked not only prevents accidental damage
to the lines, but prevents property damage and personal injuries that could result in breaking a line.

-------
NAVFAC Pacific ER Program
Utility Clearance

Procedure Number:
Revision Date:
Page:

l-A-5
May 2015
2 of 5

The following information will need to be provided when a request is placed to One-Call:

Your name, phone number, company name (if applicable), and mailing address.

What type or work is being done. This should be a description of the specific reason for the
work, not the method used.

Who the work is being done for.

The county and city the work is taking place in.

The address or the street where the work is taking place.

Marking instructions, (specific instructions as to where the work is taking place).

Under normal circumstances it takes between 2 days to 5 days from the time you call (not counting
weekends or holidays) to have the underground lines marked. Because these laws vary from state to
state, exactly how long it will take depends on where your worksite is located. You will be given an
exact start time and date when your locate request is completed, which will comply with the laws in
your area.

In the event of an emergency (any situation causing damage to life or property, or a service outage),
lines can be marked sooner than the original given time if requested, but must be handled via voice
contact with One-Call.

3.4 Toning

Toning is the process of surveying an area utilizing one or more surface geophysical methods to
determine the presence or absence of underground utilities. Typically, toning is conducted after
identifying the general location of utilities and carefully examining all available site utility plans.
Each location is marked according to the type of utility being identified. In addition, areas cleared by
toning are flagged or staked to indicate that all identified utilities in a given area have been toned.

4. Responsibilities

The prime contractor CTO Manager is responsible for verifying that these utility locating procedures
are performed prior to the initiation of active subsurface exploration. The CTO Manager is
responsible for ensuring that all personnel involved in sampling and/or testing shall have the
appropriate education, experience, and training to perform their assigned tasks as specified in Chief
of Naval Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The onsite Field Manager (FM) and Site Safety and Health Officer (SSHO) are responsible for
planning utility clearance and for locating and marking underground utilities according to this
procedure.

Field personnel are responsible for the implementation of this procedure.

-------
NAVFAC Pacific ER Program
Utility Clearance

Procedure Number:
Revision Date:
Page:

l-A-5
May 2015
3 of 5

5. Procedures

Follow the following steps at all sites where subsurface exploration will include excavations,
drilling, or any other subsurface investigative method that could damage utilities at a site. In addition
to the steps outlined below, always exercise caution while conducting subsurface exploratory work.

5.1	Prepare Preliminary Site Plan

Prepare a preliminary, scaled site plan depicting the proposed exploratory locations as part of the
work plan. Include as many of the cultural and natural features as practical in this plan.

5.2	Review Background Information

Search existing plan files to review the as-built plans and available geographic information system
databases to identify the known location of utilities at the site. In addition, the contractor should
contact the Navy RPM to obtain the most updated GIS layers. Plot the locations of utilities identified
onto a preliminary, scaled site plan. Inform the CTO Manager if utilities lie within close proximity to
a proposed exploration or excavation location. The CTO Manager will determine if it is necessary to
relocate proposed sampling or excavation locations.

Include the utility location information gathered during investigation (e.g., remedial investigation or
remedial site evaluation) work in the project design documents for removal or remedial actions. In
this manner, information regarding utility locations collected during implementation of a CTO can
be shared with the other contractors during implementation of a particular task order. In many
instances, this will help to reduce the amount of additional geophysical surveying work the other
contractor may have to perform.

Conduct interviews with onsite and facility personnel familiar with the site to obtain additional
information regarding the known and suspected locations of underground utilities. In addition, if
appropriate, contact shall be made with local utility companies to request their help in locating
underground lines. Pencil in the dimensions, orientation, and depth of utilities, other than those
identified on the as-built plans, at their approximate locations on the preliminary plans. Enter the
type of utility, the personnel who provided the information, and the date the information was
provided into the field log.

During the pre-fieldwork interviewing process, the interviewer will determine which site personnel
should be notified in the event of an incident involving damage to existing utilities. Record this
information in the field logbook with the corresponding telephone numbers and addresses.

5.3	Dig Permit

Prior to all activities requiring excavation work that may disrupt utility services, vehicular or aircraft
traffic flow, protection provided by fire and intrusion alarm systems, or routine activities at Navy
bases (including Joint Base Pearl Harbor-Hickam and Naval Base Guam), as well as intrusive work
at Marine Corps Base Hawaii, current procedures shall be followed. The dig permit process tries to
identify, as much as practical, any known, potentially hazardous work condition related to
excavation activities and is intended to prevent accidents. It also informs key Navy personnel of the
digging work and coordinates the required work with these activities to minimize inconveniences
(JBPHH 2013).

-------
NAVFAC Pacific ER Program
Utility Clearance

Procedure Number:
Revision Date:
Page:

l-A-5
May 2015
4 of 5

5.4	Site Visit - Locate Utilities - Toning

Prior to the initiation of field activities, the field task manager or similarly qualified staff personnel
shall visit the site and note existing structures and evidence of associated utilities, such as fire
hydrants, irrigation systems, manhole and vault box covers, standpipes, telephone switch boxes, free-
standing light poles, gas or electric meters, pavement cuts, and linear depression. Compare notes of
the actual site configuration to the preliminary site plan. Note deviations in the field logbook and on
the preliminary site plan. Accurately locate or survey and clearly mark with stakes, pins, flags, paint,
or other suitable devices all areas where subsurface exploration is proposed. These areas shall
correspond with the locations drawn on the preliminary site plan.

Following the initial site visit by the FM, a trained utility locator will locate, identify, and tone all
utilities depicted on the preliminary site plan. The locator should use appropriate sensing equipment
to attempt to locate utilities that might not have appeared on the as-built plans. This may involve the
use of surface geophysical methods (Procedure I-B-2, Geophysical Testing). At a minimum, use a
utility locator, metal detector, and/or magnetometer; however, it is important to consider the
possibility that non-metallic utilities or tanks might be present at the site. Use other appropriate
surface geophysical methods, such as Ground Penetrating Radar, if non-metallic cultural features are
likely to be present at the site. Clear proposed exploration areas of all utilities in the immediate area
where subsurface exploration is proposed. Clearly tone all anomalous areas. Clearly identify all
toned areas on the preliminary site plan. After toning the site and plotting all known or suspected
buried utilities on the preliminary site plan, the utility locator shall provide the FM with a copy of the
completed preliminary site plan. Alternatively, the FM or designee shall document the results of the
survey on the preliminary site plan.

Report to the FM anomalous areas detected and toned that are in close proximity to the exploration
or excavation areas. The FM shall determine the safe distance to maintain from the known or
suspected utility. It may be necessary to relocate proposed exploration or excavation areas. If this is
required, the FM or a similarly qualified individual shall relocate them and clearly mark them using
the methods described above. Completely remove the markings at the prior location. Plot the new
locations on the site plan and delete the prior locations from the plan. In some instances, such as in
areas extremely congested with subsurface utilities, it may be necessary to dig by hand to determine
the location of the utilities.

5.5	Prepare Site Plan

Prior to the initiation of field activities, draft a final site plan that indicates the location of subsurface
exploration areas and all known or suspected utilities present at the site. Provide copies of this site
plan to the Contracting Officer's Representative (COR), the CTO Manager, and the subcontractor
who is to conduct the subsurface exploration/excavation work. Review the site plan with the COR to
verify its accuracy prior to initiating subsurface sampling activities.

6. Records

Keep a bound field logbook detailing all activities conducted during the utility locating procedure.
The logbook will describe any changes and modifications made to the original exploration plan. The
trained utility locator shall prepare a report and keep it in the project file. Also keep a copy of the
final site plan on file.

-------
NAVFAC Pacific ER Program
Utility Clearance

Procedure Number:
Revision Date:
Page:

l-A-5
May 2015
5 of 5

7.	Health and Safety

Field personnel shall perform work in accordance with the current (or as contractually obligated)

United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1

(USACE 2008) and site-specific health and safety plan.

8.	References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/uip_qapp_vl_0305.pdf.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

Joint Base Pearl Harbor-Hickam (JBPHH). 2013. Dig Permit Requests. JBPHH Instruction 11013.1.
15 March 2013.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-B-2, Geophysical Testing.

9.	Attachments

None.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
1 of 35

Investigation-Derived Waste Management

1. Purpose

This standard operating procedure describes the activities and responsibilities of the United States
(U.S.) Navy Environmental Restoration (ER) Program, Naval Facilities Engineering Command
(NAVFAC), Pacific with regard to management of investigation-derived waste (IDW). The purpose
of this procedure is to provide guidance for the minimization, handling, labeling, temporary storage,
inventory, classification, and disposal of IDW generated under the ER Program. This procedure will
also apply to personal protective equipment (PPE), sampling equipment, decontamination fluids,
non-IDW trash, non-indigenous IDW, and hazardous waste generated during implementation of
removal or remedial actions. The information presented will be used to prepare and implement work
plans (WPs) for IDW-related field activities. The results from implementation of WPs will then be
used to develop and implement final IDW disposal plans.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the Uniform Federal Policy-Quality Assurance Project Plan
(DoD 2005). As professional guidance for specific activities, this procedure is not intended to
obviate the need for professional judgment during unforeseen circumstances. Deviations from this
procedure while planning or executing planned activities must be approved and documented by the
following prime contractor representatives: the CTO Manager and the Quality Assurance (QA)
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

This procedure focuses on the requirements for minimizing, segregating, handling, labeling, storing,
and inventorying IDW in the field. Certain drum inventory requirements related to the screening,
sampling, classification, and disposal of IDW are also noted in this procedure.

3.	Definitions

3.1	IDW

IDW consists of all materials generated during site investigations that might be contaminated with
chemicals of concern. IDW might consist of many types of potentially contaminated materials,
including but not limited to, PPE, disposable sampling and decontamination equipment,
investigation-derived soil, sludge, and sediment, well development and purge water, and
decontamination fluids.

3.2	PPE

PPE, as defined in this procedure, refers to all disposable materials used to protect personnel from
contact with potentially contaminated site media, such as inner and outer gloves, Tyvek suits and
overboots, and disposable respirator cartridges. Non-consumable items, such as steel-toe boots,
respirators, and hard hats are not included in this procedure.

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
2 of 35

3.3	Disposable Sampling Equipment

Disposable sampling equipment consists of all single-use equipment that might have come in contact
with potentially contaminated site media, including sample bailers, Draeger air monitoring tubes,
used soil sampling trowels and spatulas, plastic drop cloths, plastic bags and bucket liners, and
sample containers from field analytical test kits.

3.4	Investigation-Derived Soil, Sludge, and Sediment

Investigation-derived soil consists of all potentially contaminated soil that is disturbed as part of site
investigation activities. The most commonly encountered form of IDW soil is drill cuttings brought
to the ground surface by drilling. Other forms of disturbed soil, including trenching spoils and excess
soil remaining from surface sampling, should not be stored as IDW. Excavated soil should be
returned to its source if site conditions permit.

Investigation-derived sludge consists of all potentially contaminated sludge materials generated or
disturbed during site investigation activities. Generated sludge might consist of drilling mud used or
created during intrusive activities. Other sludge might include solvents or petroleum-based materials
encountered at the bottom of storage tanks and grease traps.

Investigation-derived sediment consists of all potentially contaminated sediments that are generated
or disturbed during site investigation activities. Generated sediments might include solids that settle
out of suspension from well development, purge, or decontamination water (see Definitions 3.5 and
3.6) while stored in 55-gallon drums or during sample filtration. Disturbed sediments might also
consist of catch basin sediments or excess sediment from surface water activities.

3.5	Well Development and Purge Water

Development water consists of groundwater withdrawn from newly installed monitoring wells in
preparation for well purging or pump testing. Monitoring well development methods are discussed in
Procedure I-C-2, Monitoring Well Development.

Purge water consists of groundwater that is removed from monitoring wells immediately prior to
sampling. Well purging methods are discussed in Procedure I-C-3, Monitoring Well Sampling.
Groundwater derived during aquifer testing shall be addressed on a site-specific basis. Procedures for
handling groundwater generated during aquifer testing shall be included in the WP or equivalent
document for the CTO.

3.6	Decontamination Fluids

Decontamination fluids consist of all fluids used in decontamination procedures conducted during
site investigation activities. These fluids consist of wash water, rinse water, and solvents used for the
decontamination of non-consumable PPE, sampling equipment, and drilling equipment.
Decontamination procedures are discussed in Procedure I-F, Equipment Decontamination.

3.7	Non-IDW Trash

Non-IDW trash is all waste materials, such as waste paper, drink containers, food, and packaging,
generated in the support zone that have not come in contact with potentially contaminated site media.

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
3 of 35

3.8	Non-Indigenous IDW

Non-indigenous IDW consists of all waste materials from offsite sources that are generated in the
transition or contamination reduction zones and have not come in contact with potentially
contaminated site media. Non-indigenous IDW includes materials, such as PPE from "clean" field
activities (e.g., field blank generation, water sampling events) and refuse from monitoring well
installation (e.g., unused sections of well casing, used bentonite buckets, sand bags, and cement
bags).

Non-indigenous waste does not include material/waste that is abandoned at the ER site (including the
IDW waste storage area) by other parties not associated with the ER work. Disposal of abandoned
material/waste in the vicinity of IDW is the responsibility of the property owner (e.g., Navy Region
Hawaii) or party responsible for abandoning the material/waste. The ER contractor shall notify the
Contracting Officer's Representative (COR) of the situation as soon as possible so that recovery
actions can be coordinated by the Government.

3.9	Resource Conservation and Recovery Act (RCRA) Hazardous Waste

Under the RCRA, a solid waste that is not excluded from regulation is defined as hazardous if it:

•	Is "listed" as a hazardous waste in Chapter 40, Code of Federal Regulations (CFR), Parts
261.31 through 261.33

•	Exhibits any of four hazardous "characteristics"—ignitability, corrosivity, reactivity, or
toxicity (as determined using the Toxicity Characteristic Leachate Procedure [TCLP]) (40
CFR 261.20-24)

•	Is subject to certain "mixture" or "derived-from" rules (40 CFR 261.3).

Under certain circumstances, petroleum- or polychlorinated biphenyl (PCB)-contaminated wastes are
not considered RCRA hazardous when they only exhibit toxicity characteristic (40 CFR 261.4(b)(10)
and 261.8). If IDW is determined to be RCRA hazardous waste, then RCRA storage, transport, and
disposal requirements shall apply unless exempt.

3.10	RCRA Land Disposal Restrictions (LDR)

Land disposal, as defined in RCRA, is any placement of RCRA hazardous waste on the land in a
waste pile, landfill, impoundment, well, land treatment area, etc. LDRs are regulatory restrictions
placed on land disposal, including pre-treatment standards, engineered containment, capacity
constraints, and reporting and permitting requirements.

3.11	Area of Contamination (AOC)

The U.S. Environmental Protection Agency (EPA) considers the RCRA AOC to be a single
land-based disposal unit, usually a "landfill," and includes non-discrete land areas in which there is
generally dispersed contamination. Storing IDW in a container (i.e., portable storage devices, such as
drums and tanks) within the AOC and returning it to its source, whether RCRA hazardous or not,
does not trigger RCRA LDRs. In addition, sampling and direct replacement of wastes within an
AOC do not constitute land disposal.

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
4 of 35

3.12 CERCLA Hazardous Substances

The Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA)
hazardous substances are listed in 40 CFR Table 302.4 and include substances regulated by the
RCRA Subtitle C, Clean Water Act (CWA), Clean Air Act (CAA), and Toxic Substances Control
Act (TSCA). The CFR is updated annually; therefore, the most recent CFR should be referenced for
the CERCLA hazardous waste list.

CERCLA hazardous substances are defined independent of their concentration level (i.e., any
detection of a listed CERCLA constituent is considered a "CERCLA hazardous substance").
"Reportable quantities" identified for chemicals in 40 CFR Table 302.4 concern only CERCLA and
RCRA requirements for notification to EPA when a release has occurred; they do not dictate whether
a chemical is a hazardous substance.

The definition of CERCLA hazardous substances excludes "petroleum, including crude oil or any
fraction thereof;" natural gas; natural gas liquids; liquefied natural gas; and synthetic gas usable for
fuel, unless specifically listed or designated under the act. Excluded fractions of crude oil contain
hazardous substances, such as benzene, that are indigenous in those petroleum substances or that are
normally mixed with or added to petroleum during the refining process. However, hazardous
substances that are (1) added to petroleum after the refining process, (2) increase in concentration as
a result of contamination of the petroleum during use, or (3) commingled with petroleum after a
release to the environment, are not considered part of the petroleum exclusion provision, and
therefore, are regulated under CERCLA. In addition, some waste oils are regulated under CERCLA
because they are specifically listed.

The scope of CERCLA hazardous substances includes the smaller subsets of RCRA hazardous
wastes, PCB Aroclors, and other constituents. Therefore, a RCRA hazardous waste is always
considered a CERCLA hazardous substance for a CERCLA-driven response action; however, a
CERCLA hazardous substance is not always a RCRA hazardous waste.

CERCLA only regulates releases or threats of releases of hazardous substances into the
environment. If there is no evidence that (1) a release has occurred (based on site history, visual
observations, background metals evaluation), (2) there is a threat of release (as from abandoned,
discarded, or non-maintained chemical receptacles), or (3) the release has entered the environment
(as defined below), then CERCLA does not regulate the constituent even though it is identified on
the CERCLA hazardous substance list.

3.12.1 CERCLA Hazardous Substances: TSCA/PCBs

PCBs are a CERCLA hazardous substance. PCBs belong to a broad family of man-made organic
chemicals known as chlorinated hydrocarbons. PCBs were domestically manufactured from 1929
until their manufacture was banned in 1979. They have a range of toxicity and vary in consistency
from thin, light-colored liquids to yellow or black waxy solids. Due to their non-flammability,
chemical stability, high boiling point, and electrical insulating properties, PCBs were used in
hundreds of industrial and commercial applications including electrical, heat transfer, and hydraulic
equipment; as plasticizers in paints, plastics, and rubber products; in pigments, dyes, and carbonless
copy paper; and many other industrial applications. Although no longer commercially produced in
the United States, PCBs may be present in products and materials produced before the 1979 PCB
ban.

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
5 of 35

If PCBs are detected at concentrations equal to or greater than 50 parts per million (ppm), the sample
is considered TSCA-regulated. Current PCB regulations can be found in the CFR at 40 761. The
EPA Q and A Manual (EPA 2009), referring to CFR 761.61 explains PCB remediation waste must
be managed and disposed of based on the concentration at which the PCBs are found. It is
unacceptable to dilute the as-found concentration of the contaminated soil by mixing it with clean
soil during excavation or other IDW management activities.

3.13	Environment

Environment means navigable waters, ocean waters, surface water, groundwater, drinking water
supply, land surface or subsurface strata, and ambient air, within the U.S. or under federal
jurisdiction (see Section 101(8) of CERCLA or 40 CFR 300.5 for complete definition).

3.14	OnsiteArea

The CERCLA onsite area is defined in 40 CFR 300.400(e)(1) as an area that includes:

•	All suitable areas in very close proximity to the contamination that are necessary for the
implementation of the response action

The delineation of the onsite area is further discussed in Volume 55 Federal Register (FR) Page 8688
and EPA guidance.

Neither CERCLA, the National Oil and Hazardous Substances Pollution Contingency Plan, nor
RCRA define the terms "area of contamination" or "contamination." However, the area of
contamination is interpreted as containing "varying types and concentrations of contaminants" (55
FR 8760) that may or may not pose a risk to human health or the environment.

The onsite area may also include several noncontiguous aerial extents of contaminations if they share
a common nexus (55 FR 8690).

3.15	OffsiteArea

The offsite area consists of all areas outside the onsite area.

3.16	CERCLA Offsite Rule

The CERCLA offsite rule (400 CFR 300.440) states that IDW containing CERCLA hazardous
substances (at any concentration) must be stored, treated, or disposed of offsite only at facilities
having current EPA approval to accept such CERCLA wastes. RCRA-permitted facilities (Subtitle C
and D) must also have specific EPA approval to accept waste generated at a CERCLA site (even if
the waste is RCRA hazardous).

With some restrictions, the offsite rule does not apply to the following:

•	Wastes generated during non-CERCLA actions

• AOC

Treatability study samples

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
6 of 35

•	Wastes generated during emergency response actions

•	Laboratory samples

CERCLA allows IDW to be managed, stored, and disposed of onsite within or near the AOC without
the need for EPA approval (i.e., CERCLA facility approval) or RCRA permits. If IDW is to be
stored or disposed of on site, the onsite area (and the AOC) should be delineated on a figure in the
project field book and revised, based on best professional judgment, as site data become available.

4.	Responsibilities

The prime contractor CTO Manager is responsible for preparing WPs and IDW disposal plans and
reports in compliance with this procedure, and is responsible for documenting instances of
noncompliance. The CTO Manager is responsible for ensuring that all personnel involved in
sampling and/or testing shall have the appropriate education, experience, and training to perform
their assigned tasks as specified in Chief of Naval Operations Instruction 5090.1, under Specific
Training Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The Field Manager is responsible for implementing this IDW procedure and ensuring that all project
field staff follow these procedures.

Field personnel are responsible for the implementation of this procedure.

5.	IDW Management Procedures

The procedures for IDW management in the field are described below.

5.1 Planning for IDW Management

The project team should begin planning for IDW issues early in the site investigation planning stage.
The proper management of IDW involves all of the following tasks:

•	Obtain Navy approval for a designated IDW storage area prior to commencement of field
work

- Complete Navy form, including IDW Tracking Sheet and provide to remedial project
manager (RPM) for processing

•	Waste generation and minimization

•	Chemical screening and characterization of the waste

•	Waste handling, storage, and associated maintenance in compliance with all regulations
(prepare an IDW drum inventory, ensure storage areas are compliant with type of waste
[double containment, TSCA requirements, etc.] maintain condition of drum and labeling,
maintain safety and assess controls, comply with permit requirements [for offsite storage])

•	Waste transport and disposal within required holding times

•	Waste tracking, documentation, record keeping, and reporting

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
7 of 35

As part of IDW planning, the CTO Manager should consult with the COR and environmental
regulatory agencies to clearly identify the primary federal or state regulatory authority that is driving
the site investigation. This authority may be CERCLA, RCRA (Subtitle C), RCRA (subtitle I),
TSCA, CWA, or an equivalent state program. The primary investigation authority and regulations
promulgated under this authority set forth requirements for IDW management. These requirements
may differ under the various response authorities. For CERCLA-driven actions, IDW storage and
disposal should comply with all applicable or relevant and appropriate requirements (ARARs) and
to-be-considered (TBC) criteria to the extent practicable.

Lastly, the CTO Manager should consider the disposal criteria of the anticipated disposal facility
when developing the sampling and analysis plan (SAP). Some offsite facilities do not accept waste
that is characterized by association with samples collected from the investigation site or they may
require analytical data for chemicals that are not of potential concern at the site. Facility disposal
criteria may dictate laboratory reporting limits.

If unknown waste is observed onsite, notify the project RPM and COR for further instructions.
5.2 IDW Minimization

Field managers (FMs) and their designates shall minimize the generation of onsite IDW to reduce the
need for special storage or disposal requirements that might result in substantial additional costs and
provide little or no reduction in site risks (EPA 1992b). Reduce the volume of IDW by applying
minimization practices throughout the course of site investigation activities. These minimization
strategies include substitution of biodegradable raw materials; using low-volume IDW-generating
drilling techniques; where possible, returning excess material to the source location; using disposable
sampling equipment versus generating more decontamination fluids from reusable sampling
equipment; using bucket and drum liners; and separating trash from IDW.

Material substitution consists of selecting materials that degrade readily or have reduced potential for
chemical impacts to the site and the environment. An example of this practice is the use of
biodegradable detergents (e.g., Alconox or non-phosphate detergents) for decontamination of non-
consumable PPE and sampling equipment. In addition, field equipment decontamination can be
conducted using isopropyl alcohol rather than hexane or other solvents (for most analytes of
concern) to reduce the potential onsite chemical impacts of the decontamination solvent. Select
decontamination solvents carefully so that the solvents, and their known decomposition products, are
not potentially RCRA hazardous waste, unless absolutely necessary.

Give priority to drilling methods that minimize potential IDW generation. Select hollow-stem auger
and air rotary methods, where feasible, over mud rotary methods. Mud rotary drilling produces waste
drilling mud, while hollow stem and air rotary drilling methods produce relatively low volumes of
soil waste. Use small-diameter borings and cores when soil is the only matrix to be sampled at the
boring location; however, the installation of monitoring wells requires the use of larger-diameter
borings.

If possible, return soil, sludge, or sediment removed from borings, containment areas, and shallow
test trenches to the source immediately after sampling and/or geological logging of the soils (EPA
1991, 1992b). Immediate replacement of solid waste in the source location during investigation
activities avoids RCRA LDRs, which permit movement of IDW within the same AOC without
considering land disposal to have occurred, even if the IDW is later determined to contain RCRA

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
8 of 35

hazardous material (EPA 1991). Place soil IDW from borings and trenches on polyethylene sheeting
(e.g., Visqueen) during excavation and segregate it by approximate depth and any apparent
contamination (i.e., visible staining). Following excavation, replace the soil IDW from above the
saturated layer into the boring or trench and compact it, if possible. Efforts should be made to return
the waste to the approximate depth from which it was generated. Soil and sludge IDW generated at
or below the saturated layer of a boring or trench should be placed in drums and not returned to the
source area. Suspected contaminated soil and sludge IDW generated above the saturated layer of a
boring or trench should not be returned below the saturated layer."

Often monitoring wells are constructed outside the area of concern for soil contamination to sample
for potential groundwater contamination or collect characteristic background data. At these locations,
soil cuttings generated from above the saturation zone may be immediately disposed of near the
wellhead in a shallow pit covered with natural topsoil from the site, and compacted. Contain soil and
sludge IDW generated at or below the saturated layer in drums.

Reduce the quantity of decontamination rinse water generated by using dedicated and disposable
sampling equipment, such as plastic bailers, trowels, and drum thieves that do not require
decontamination. In general, decontamination fluids, and well development and purge water should
not be minimized because the integrity of the associated analytical data might be affected.

Minimize the storage of visibly soiled PPE and disposable sampling equipment IDW by
implementing decontamination procedures. If, based upon the best professional judgment of the FM,
the PPE and disposable sampling equipment can be rendered non-contaminated after
decontamination, then double-bag the PPE and disposable sampling equipment and dispose of it off
site at a (RCRA Subtitle D) municipal solid waste disposal facility at the end of each work day
(EPA 1991, 1992b). Since the decontaminated waste does not contain CERCLA hazardous
substances, it need not be disposed of at a CERCLA-approved disposal facility in accordance with
the CERCLA offsite rule.

Bucket liners can be used in the decontamination program to reduce the volume of solid IDW
generated, and reduce costs on larger projects. The plastic bucket liners can be crushed into a smaller
volume than the buckets, and only a small number of plastic decontamination buckets are required
for the entire project. The larger, heavy-duty, 55-gallon drum liners can be used for heavily
contaminated IDW to provide secondary containment, and reduce the costs of disposal and drum
recycling. Drum liners may extend the containment life of the drums in severe climates and will
reduce the costs of cleaning out the drums prior to recycling.

All waste materials generated in the support zone are considered non-IDW trash. To minimize the
total volume of IDW, separate all trash from IDW, seal it in garbage bags, and properly dispose of it
off site as municipal waste at the end of each work day.

Keep excess cement, sand, and bentonite grout prepared for monitoring well construction to a
minimum. FMs shall observe well construction to ensure that a sufficient, but not excessive, volume
of grout is prepared. Some excess grout may be produced. Unused grout (that should not come in
contact with potentially contaminated soil or groundwater) shall be considered non-hazardous trash,
and the drilling subcontractor shall dispose of it off site. Surplus materials from monitoring well
installation, such as scrap plastic sections, used bentonite buckets, and cement/sand bags that do not

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
9 of 35

come in contact with potentially contaminated soil, shall be considered non-IDW trash, the drilling
subcontractor shall dispose of it off site.

Following proper segregation procedures, as discussed in the next section, can minimize the quantity
of contaminated IDW generated.

5.3 Segregation of IDW by Matrix and Location

It is necessary to properly segregate IDW in order to:

•	Avoid commingling contaminated waste with clean waste, thereby creating a larger volume
of waste that must be treated as contaminated

•	Facilitate the sampling, screening, classification, and disposal of waste that may require
different management methods

Take efforts to segregate IDW even when these activities will increase storage container and storage
space requirements. These efforts will drastically reduce the sampling and documentation required
for characterizing the waste and their associated costs.

In general, segregate IDW by matrix and source location and depth at the time it is generated. IDW
from only one matrix shall be stored in a single drum (e.g., soil, sediment, water or PPE shall not be
mixed in one drum). Groundwater and decontamination water should not be commingled; however,
development and purge water from the same well may be stored together.

In general, IDW from separate sources should not be combined in a single drum or stockpile. Take
efforts to segregate waste by increments of depth below ground surface. Most importantly, segregate
soil IDW generated at or from below the saturated zone from soil generated above this zone (soil
below this zone might be impacted by contaminated groundwater, whereas soil above the zone may
be "clean"). Similarly, segregate soil above and below an underground storage tank (UST). Label
each drum of soil to indicate the approximate depth range from which it was generated; this task may
require cuttings to be segregated on plastic sheeting as they are generated or drums to be filled
during the trenching or boring operation if this can be done in a safe manner.

It is possible that monitoring well development and purge water will contain suspended solids, which
will settle to the bottom of the storage drum as sediment. Include significant observations on the
turbidity or sediment load of the development or purge water in the logbook see Procedure III-D,
Logbooks and Section 5.5). To avoid mixed matrices in a single drum (i.e., sediment and water), it
may be necessary to decant the liquids into a separate drum after the sediments have settled out. This
segregation may be accomplished during subsequent IDW sampling activities or during
consolidation in a holding tank prior to disposal.

Place potentially contaminated well construction materials in a separate drum. No soil, sediment,
sludge, or liquid IDW shall be placed in drums with potentially contaminated waste well
construction materials. In addition, potentially contaminated well construction materials from
separate monitoring wells shall not be commingled.

Store potentially contaminated PPE and disposable sampling equipment in drums separate from
other IDW. Segregate PPE from generally clean field activities, such as water sampling, from visibly

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
10 of 35

soiled PPE, double-bag it, and dispose of it off site as municipal waste. Disposable sampling
equipment from activities, such as soil, sediment, and sludge sampling, includes plastic sheeting used
as liner material in containment areas around drilling rigs and waste storage areas, disposable
sampling equipment, and soiled decontamination equipment. If, according to the Field Manager's
best professional judgment, the visibly soiled PPE can be decontaminated and rendered
non-hazardous, then double-bag the decontaminated PPE and disposed of it off site as municipal
waste (EPA 1991, 1992b). PPE and disposable sampling equipment generated on separate days in
the field may be combined in a single drum, provided clean and visibly soiled IDW are segregated as
discussed above.

IDW generated from the use of field analytical test kits consists of those parts of the kit that have
come into contact with potentially contaminated site media, and used or excess extracting solvents
and other reagents. Contain potentially contaminated solid test kit IDW in plastic bags and store it
with contaminated PPE or disposable sampling equipment IDW from the same source area as soil
material used for the analyses. Segregate the small volumes of waste solvents, reagents, and water
samples used in field test kits, and dispose of it accordingly (based upon the characteristics of the
solvents as described in this procedure). Most other test kit materials should be considered non-IDW
trash, and be disposed of as municipal waste.

Store decontamination fluids in drums separate from groundwater and other IDW. If practical,
decontamination fluids generated from different sources should not be stored in the same drum. If
decontamination fluids generated over several days or from different sources are stored in a single
drum, record information about the dates and IDW sources represented in the drum. Note this
information in the field notebook, on the drum label (Section 5.4.3), and in the drum inventory
(Section 5.5).

The FM and designated personnel should separate the liquid and sediment portions of the equipment
decontamination fluid present in the containment unit used by the drilling or excavation field crew.
The contents of this unit normally consist of turbid decontamination fluid above a layer of
predominantly coarse-grained sediment. When the contents of the containment unit are to be
removed for storage in IDW drums, the FM shall instruct the field crew to place as much of the
liquid into drums as possible and transfer the remaining solids into separate drums. Note
observations of the turbidity and sediment load of the liquid IDW in the field notebook, on the drum
label (Section 5.4.3), and in attachments to the drum inventory (Section 5.5). It is likely that
decontamination fluids will contain minor amounts of suspended solids that will settle out of
suspension to become sediment at the bottom of IDW storage drums. As noted above, it may be
necessary to segregate the drummed water from sediment during subsequent IDW sampling or
disposal activities.

Documentation for waste storage containers should include IDW source and segregation information
and be maintained as follows:

1.	Field logbook should be updated, at least weekly, with all IDW drum additions - update
storage area location map to include new drum position and drum number.

2.	External drum log (hard copy and electronic copy) should be updated with each IDW drum
addition (drum numbers, source, and generation date) and closure of drum (fill date).

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
11 of 35

5.4 Drum Filling, Handling, and Labeling, and Inventorying

Drum handling consists of those actions necessary to prepare an IDW drum for labeling. Drum
labeling consists of those actions required to legibly and permanently identify the contents of an
IDW drum.

5.4.1	Drum Filling

Each drum of solid IDW shall be completely filled, when possible. For liquid IDW, drums should be
left with headspace of approximately 5 percent by volume to allow for expansion of the liquid and
potential volatile contaminants.

5.4.2	Drum Handling

IDW shall be containerized using U.S. Department of Transportation-(DOT) approved drums. The
drums shall be made of steel or plastic, have a 55-gallon capacity, be completely painted or opaque,
and have removable lids (i.e., United Nations Code 1A2 or 1H2). Drums having removable lids with
bung holes are preferred to facilitate verification of drum contents. Typically 55-gallon drums are
used, however small drums may be used depending on the amount of waste generated. New steel
drums are preferred over recycled drums. Recycled drums should not be used for hazardous waste,
PCBs or other regulated shipments. For short-term storage of liquid IDW prior to discharge,
double-walled bulk steel or plastic storage tanks may be used. For this scenario, consider the
scheduling and cost-effectiveness of this type of bulk storage, treatment, and discharge system versus
longer-term drum storage.

The Guam Environmental Protection Agency may require double-walled drums or other secondary
containment for the storage of liquid IDW. For long-term IDW storage at other project locations, the
DOT-approved drums with removable lids are recommended. Verify the integrity of the foam or
rubber sealing ring located on the underside of some drum lids prior to sealing drums containing
IDW liquids. If the ring is only partially attached to the drum lid, or if a portion of the ring is
missing, select another drum lid with a sealing ring that is in sound condition.

To prepare IDW drums for labeling, wipe clean the outer wall surfaces and drum lids of all material
that might prevent legible and permanent labeling. If potentially contaminated material adheres to
the outer surface of a drum, wipe that material from the drum, and segregate the paper towel or rag
used to remove the material with visibly soiled PPE and disposable sampling equipment. Label all
IDW drums and place them on appropriate pallets prior to storage.

5.4.3	Drum Labeling

Proper labeling of IDW drums is essential to the success and cost-effectiveness of subsequent waste
screening and disposal activities (see Attachment I-A-6-1 and Attachment I-A-6-2). Labels shall be
permanent and descriptive to facilitate correlation of field analytical data with the contents of
individual IDW drums. Label all IDW drums using the three distinct labeling methods described
below to ensure durability of the information. These three methods are completing and affixing
preprinted NAVFAC Pacific ER Program labels; marking information on drum surfaces with paint;
and, affixing aluminum tags to the drum. Use of the preprinted labels, painted labeling, and
aluminum tags is mandatory. These methods are described below.

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
12 of 35

5.4.3.1 Preprinted Labels

Complete two preprinted NAVFAC Pacific ER Program drum labels as described below and
presented in Attachment I-A-6-1. Seal both labels in separate heavy-duty, clear plastic bags, or use
permanent markers on weatherproof stickers, to prevent moisture damage.

1.	Place one label on the outside of the drum with the label data facing outward. Affix the
bag/sticker to the drum at the midpoint of the drum height using a sufficient quantity of
adhesive tape (e.g., duct tape, packing/strapping tape) so the bag will remain on the drum as
long as possible during storage.

2.	Affix the second label (sealed as mentioned above) to the underside of the drum lid, sealing
it inside the drum when the lid is replaced.

The use of two or more preprinted labels for outer IDW drum identification purposes should be
considered as a short-term backup to the information on the aluminum tags discussed below.

Print the requested information legibly on the drum labels in black, indelible ink. Instructions for
entering the required drum-specific information for each label field are presented below:

CTO: Enter the four-digit number of the CTO for the project during which the IDW was generated.
Include any initial zeroes in the CTO number (e.g., CTO 0047).

Activity-Site: Enter the name of the Navy activity responsible for the project site (e.g., Naval Supply
Center, Naval Facilities Engineering Command Hawaii) and the name of the site where the project is
taking place (e.g., Orote, Landfill, Building [Bldg.] 18).

Drum#: Enter the drum identification number according to the convention described below.
(xxxx-AA-DMzzz);

xxxx represents the four-digit CTO number

AA represents the unique site identifier assigned by the CTO Manager for multiple site
CTOs (e.g., for CTO 0047, OW denotes Old Westpac, OR denotes Orote)

DM represents a drum identification number

zzz the sequential drum number for the site, beginning with 001

Date Collected: Enter the date the IDW was generated and placed in the drum. If IDW was
generated over a number of days, enter the start and end dates for the period.

Contents: Record the source identification number on the label. Enter a "V" in the box corresponding
to the type of IDW placed in the drum. For "Soil" and "Water," use the line provided to record
observations on the condition of the drum contents (e.g., diesel odor, high turbidity, specific liquid
IDW type). Check "Solid Waste" for PPE and indicate that PPE is present in the drum. Check

Where:

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
13 of 35

"Other" for disposable sampling equipment and potentially contaminated monitoring well
construction materials, and indicate the type of waste on the line provided.

Project Type: Enter a "V" in the box corresponding to the type of investigation. Choices are
Remedial Investigation, RCRA Facility Inspection, UST, and Other. If "Other" is specified, indicate
the type of project in the "Comments" area, as described below.

Comments: Enter any additional information regarding the drum contents that will assist individuals
who will characterize and dispose of the contents of the drum. "Other" project types include Site
Inspection, Feasibility Study, Removal/Remedial Action, and Emergency Response activity. In
addition, use this space on the label to complete any descriptions that were too large to fit in
preceding label fields, such as the turbidity of decontamination water or the site activities from
which the PPE was generated.

For Information Contact: Enter the project COR activity / code, address, and phone number.

It is essential that all relevant information recorded on individual drum labels be repeated in the field
notebook for later development of the drum inventory database (see Section 5.5 and Procedure III-D,

Logbooks).

5.4.3.2	Painted Labels

The second method for labeling drums is to paint label information directly on the outer surface of
the drum. At a minimum, the information placed on the drum shall include the CTO number, the
drum number (following the numbering convention given above), the source identification number
and type, the generation date(s), and the telephone number provided at the bottom of the preprinted
label appropriate for the project location. The drum surface shall be dry and free of material that
could prevent legible labeling. Confine label information to the upper two-thirds of the total drum
height. The top surface of the drum lid may be used as an additional labeling area, but this area
should only be used in addition to the upper two-thirds of the sides of the drum. The printing on the
drum shall be large enough to be easily legible. Yellow, white, black, or red paint markers (oil-based
enamel paint) that are non-photodegradable are recommended to provide maximum durability and
contrast with the drum surface.

5.4.3.3	Aluminum Tags

The third method for labeling drums is to affix an aluminum tag to the drum with neatly printed
information that shall consist of the CTO number, the drum identification number, the type of
contents, the generation date(s), the source identification number and type, and the telephone
number provided at the bottom of the appropriate preprinted label. Attachment I-A-6-2 to this
procedure presents an example of the aluminum tag, which shall measure approximately 1 inch by 3
inches, or larger. When a ballpoint pen is used to fill out the aluminum tag, the information is
permanently recorded as indentations on the tag. A fine ballpoint pen shall be used, and
block-printed lettering is required for legibility. Indentations on the tag shall be sufficiently deep to
be legible after the label has been exposed to weathering for an extended period.

Complete aluminum tags after the drum has been sealed. Affix the tags to the drum using a wire,
which passes through predrilled holes in the label and shall be wrapped around the bolt used to seal
the drum lid. The wire is the most likely part of the aluminum tag to decay during exposure. Use of

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
14 of 35

plastic insulated, copper-core electrical wire of appropriate diameter is recommended if long-term
exposure to severe weathering is anticipated.

5.4.3.4 Waste Labels

Standard green and white non-hazardous and/or other hazardous waste stickers may be used in
conjunction with, but not in lieu of, the above labeling procedures.

5.5 Drum Inventory

Accurate preparation of an IDW drum inventory is essential to all subsequent activities associated
with IDW drum tracking and disposal. Prepare an inventory for each project in which IDW is
generated, stored, and disposed of. This information provided in the inventory report constitutes the
results of preparing and implementing an IDW sampling, screening, characterization, and disposal
program for each site.

The drum inventory information shall include 10 elements that identify drum contents and indicate
their outcome. These elements are discussed in Sections 5.5.1 through 5.5.10.

5.5.1	Navy Activity (Generator)/Site Name

Inventory data shall include the Navy activity and the site name where the IDW was generated (e.g.,
Fleet Industrial Supply Center Pearl/Red Hill, Naval Magazine Headquarters/USTs).

5.5.2	CTO Number

Inventory data shall include the four-digit CTO number associated with each drum (e.g., 0089) and
contract number as necessary.

5.5.3	Drum Number

Include the drum number assigned to each drum in the inventory database. Drum numbers shall
adhere to the numbering convention presented in Section 5.4.3.1 (e.g., 0091-LF-DM006).

5.5.4	Storage Location Prior to Disposal

Include the storage location of each drum prior to disposal in the inventory database (e.g., Bldg. 394
Battery Disassembly Area, or Adjacent to West end of Bldg. 54). As part of the weekly inventory, a
site visit to the IDW storage location shall be performed to observe the condition of the drums and
covers. Drums and covers are considered acceptable when the integrity of the drums and covers are
structurally intact, drum identification is legible, and the location of the drum storage is secure. An
unacceptable classification will require recommendations to remedy the unacceptable classification.

5.5.5	Origin of Contents

Specify the source identification of the contents of each IDW drum in the inventory database (e.g.,
soil boring number, monitoring well number, sediment sampling location, or the multiple sources for
PPE- or rinse water-generating activities).

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
15 of 35

5.5.6	IDW Type

Inventory data shall include the type of IDW in each drum (e.g., soil, PPE, disposable sampling
equipment, sludge, sediment, development water, steam cleaning water, decontamination rinse
water).

5.5.7	Waste Volume

Specify the amount of waste in each drum in the inventory database as a percentage of the total drum
volume or an estimated percentage-filled level (e.g., 95 percent maximum for liquid IDW).

5.5.8	Generation Date

Inventory data shall include the date IDW was placed in each drum. If a drum contains IDW
generated over more than one day, the start date for the period shall be specified in dd-mmm-yy
format. This date is not to be confused with a RCRA hazardous waste accumulation date (40 CFR
262).

5.5.9	Expected Disposal Date

Specify the date each drum is expected to be disposed of as part of the inventory in mmm-yy format.
This date is for the Navy's information only and shall not be considered contractually binding.

5.5.10	Actual Disposal Date

The actual drum disposal date occurs at the time of onsite disposal, or acceptance by the offsite
treatment or disposal facility. Enter this date in the drum inventory data base only when such a date
is available in dd-mmm-yy format.

Information required to complete all 10 of the inventory elements for the monthly inventory report
described above and summarized in Attachment I-A-6-3, will be located on the IDW labels or
provided by the CTO Manager.

Actual disposition of the IDW drum contents will be provided to the Navy.
5.6 IDW Classification

In general, the CTO Manager should follow IDW classification guidance contained in the Generic
IDW Disposal Plans for Hawaii and Guam (Ogden 1994, 1995) and EPA guidance (EPA 1991,
1992a). The IDW classification process consists of chemical screening and characterization of the
waste.

Various federal and state laws and guidance contain requirements for IDW management (handling,
storage, transport, disposal, and recordkeeping) based on the type(s) and concentrations of chemicals
present in the waste. To ensure that IDW is managed in compliance with these requirements and to
evaluate disposal options, the CTO Manager should

•	Directly sample and analyze the IDW or associate it with historical data, observed site
conditions, and/or samples collected on site at the source of the waste

•	Screen the waste to identify the maximum concentrations of individual chemicals in, or
associated with, the waste

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
16 of 35

•	Screen waste constituents against chemical background data, if available

•	Characterize the waste based on regulated groups of chemical constituents present in the

•	Screen waste constituents against risk-based health criteria, ARARs, and TBC criteria for
onsite disposal, or disposal facility criteria for offsite disposal

Each of the above steps is distinct and should be performed separately to avoid potential mistakes in
the IDW classification process. The following subsections discuss these steps in greater detail.

5.6.1	IDW Sampling and Chemical Screening

IDW should be screened to identify chemicals present in the waste and their maximum
concentrations. Screening may be facilitated by (1) directly sampling the waste, (2) associating the
waste with analytical results from samples collected at the source of the IDW (e.g., a well boring),
(3) visual observation of the waste, (4) historical activity data from the site, or (5) a combination of
these methods (e.g., association with limited sampling). Composite sampling may be required if the
unit volume of IDW is non-homogeneous. Data from samples collected directly from the IDW
should take precedence over associated site sample data when making waste management decisions.
Procedure I-D-l, Drum Sampling discusses methods for drum sampling.

Typically, IDW is screened for chemicals of potential concern at the site and against background
data if available. If IDW is generated from outside the suspected AOC (e.g., soil cuttings from the
installation of a background monitoring well), assume it is clean, and dispose of it accordingly.

The CTO Manager should consider the disposal criteria of any offsite disposal facility anticipated to
be used when developing the SAP. Some offsite facilities do not accept waste that is characterized by
association with samples collected from the investigation site or they may require analytical data for
chemicals that are not of potential concern at the site. Direct sampling and analysis of the waste may
be required for these other constituents. Some disposal facilities prefer to collect and analyze the
samples themselves. In addition, disposal facility criteria may dictate laboratory reporting limits.
When possible, the CTO Manager should coordinate sampling and data requirements with the
disposal subcontractor and anticipated disposal facility. Such efforts may allow IDW sampling to be
conducted while the field team is mobilized for the site investigation, rather than conducting a
separate IDW sampling event later.

5.6.2	IDW Characterization

Various federal and state laws and guidance contain requirements for IDW management (handling,
storage, transport, disposal, and recordkeeping) based on the particular constituent or group(s) of
chemical constituents present in the waste. Therefore, to ensure that IDW is managed in compliance
with these requirements, characterize IDW based on the chemical screening results to determine
whether any of the following regulated constituents are present in the waste:

•	Petroleum hydrocarbons (regulated by RCRA Subtitle I when released from a UST; see 40
CFR Part 280)

•	Hazardous wastes (regulated by RCRA Subtitle C; see 40 CFR 261-299)

•	Non-hazardous, solid wastes (regulated by RCRA Subtitle D; see 40 CFR 257-258)

waste

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
17 of 35

•	Hazardous substances and commingled petroleum (regulated by CERCLA; see 40 CFR
300.400 and 302.4)

•	PCBs (regulated by TSCA; see 40 CFR 700)

•	Asbestos (regulated by CAA for disposal; see 40 CFR 61, Subpart M)

•	Radioactive wastes (regulated by the Nuclear Regulatory Commission; see 10 CFR [various
parts], 40 CFR, Subchapter F, and other applicable laws)

EPA regulations and guidance do not require IDW to be tested to properly characterize it. Instead
waste may be characterized based on historical site data, site observations, analytical data from the
source of the IDW, and professional judgment (EPA 1991). Specifically, the EPA has indicated that
IDW may be assumed not to be "listed" wastes under RCRA unless available information about the
site suggests otherwise (53 FR 51444). Similarly, RCRA procedures for determining whether waste
exhibits RCRA hazardous characteristics do not require testing if the decision can be made by
"applying knowledge of the hazard characteristic in light of the materials or process used" (40 CFR
262.11(c); EPA 1991). If applicable, the disposal plans and reports should state, "there is no
evidence based on site data and observations that the IDW contains listed RCRA wastes or exhibits
RCRA characteristics."

For soil IDW, the potential for exhibiting toxicity may be determined by comparing constituent
concentrations in the waste against screening values that are 20 times the TCLP criteria as specified
in Section 1.2 of EPA Method Solid Waste-846 1311 Toxicity Characteristic Leaching Procedure
(EPA 2007). Otherwise, samples associated with the soil can be tested using the TCLP.

5.7 IDW Storage

In general, the CTO Manager should follow IDW storage guidance contained in the Generic IDW
Disposal Plans for Hawaii and Guam (Ogden 1994, 1995) and EPA guidance (EPA 1990, 1991,
1992a).

Always store IDW in a manner that is secure, protected from weather, and protective of human
health and the environment. It is preferable to store IDW within the AOC(s) or on site; however, the
Navy may assign a specific IDW storage area away from the project site.

If the IDW is determined to be RCRA hazardous, then RCRA storage, transport, and disposal
requirements may apply, including a limited 90-day storage permit exemption period prior to
required disposal. If onsite disposal is an option, store RCRA waste within the AOC so that RCRA
LDRs will not apply in the future. LDRs may be triggered if the waste is stored within the onsite
area, but outside of the AOC or if the waste is removed from and later returned to the AOC for
disposal. The AOC concept does not affect the approach for managing IDW that did not come from
the AOC, such as PPE, decontamination equipment and fluids, and groundwater. If RCRA
hazardous, these wastes must be managed under RCRA and drummed and disposed of off site
(EPA 1991).

RCRA waste should not be stored within the AOC prior to disposal when professional judgment
suggests the IDW might pose an immediate or permanent public endangerment (EPA 1991b).

Offsite storage of CERCLA waste must comply with the CERCLA offsite rule (40 CFR 300.440).

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
18 of 35

If the IDW is determined to be TSCA-regulated, then TSCA storage requirements as described in
CFR 764.65, transport, and disposal requirements apply, including a limited 30-day storage period
prior to required disposal. Storage requirements are as follows:

1.	Storage facilities must provide an adequate roof and walls to prevent rain water from
reaching the stored PCBs.

2.	Storage facilities must provide an adequate floor that has continuous curbing with a
minimum 6-inch-high curb.

3.	Storage facilities must contain no drain valves, floor drains, expansion joints, sewer lines, or
other openings that would permit liquids to flow from the curbed area.

4.	Storage facilities must provide floors and curbing constructed of continuous smooth and
impervious materials to minimize penetration of PCBs.

5.	Storage facilities must not be located at a site that is below the 100-year flood water
elevation.

6.	PCBs in concentrations of 50 ppm or greater must be disposed of within 1 year after being
placed in storage.

PCB waste can also be stored in a RCRA-approved waste storage area for 30 days from date of
generation.

NAVFAC Pacific requires that all CERCLA, RCRA, and other types of waste be removed from
JBPHH areas within 90 days of its generation, particularly within the shipyard area, and 30 days of
generation for TSCA waste. Efforts should also be made to dispose of IDW within the 30- and 90-
day periods at other Navy installations, unless the IDW will be managed with remediation waste to
be generated during a cleanup action in the near future. The Navy may approve extensions of the
storage time limit for wastes that are non-hazardous on a project-specific basis.

5.7.1 Drum Storage

Implement drum storage procedures to minimize potential human contact with the stored IDW and
prevent extreme weathering of the stored drums. Place all IDW drums upright on pallets before the
drums are stored. RCRA storage requirements include the following: containers shall be in good
condition and closed during storage; wastes shall be compatible with containers; storage areas shall
have a containment system; and spills or leaks shall be removed as necessary.

Place all IDW drums generated during field activities at a single AOC or designated IDW storage
area together in a secure, fenced onsite area to prevent access to the drums by unauthorized
personnel. When a secure area is not available, place drums in an area of the site with the least
volume of human traffic. At a minimum, place plastic sheeting (or individual drum covers) around
the stored drums. Post signage at the IDW storage area stating that drums should not be removed
from the area without first contacting the Navy COR.

Liquid IDW drums must be stored under secondary containment (either secondary containment
pallets or handmade plastic sheeting/polyvinyl chloride frame containment) and all IDW drums (soil

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
19 of 35

and water) must utilize secondary containment when stored within 15 feet of a surface water body or
storm drain inlet.

Drums from projects involving multiple AOCs shall remain at the respective source areas where the
IDW was generated. IDW should not be transferred off site for storage elsewhere, except under rare
circumstances, such as the lack of a secure onsite storage area.

Implement proper drum storage practices to minimize damage to the drums from weathering and
possible human exposure to the environment. When possible, store drums in dry, shaded areas and
cover them with impervious plastic sheeting or tarpaulin material. Make every effort to protect the
preprinted drum labels from direct exposure to sunlight, which causes ink on the labels to fade. In
addition, store drums in areas that are not prone to flooding. Secure the impervious drum covers
appropriately to prevent dislodging by the wind. It may be possible to obtain impervious plastic
covers designed to fit over individual drums; nonetheless, repeat the labeling information on the
outside of these opaque covers.

Drums in storage shall be placed with sufficient space between rows of drum pallets and shall not be
stacked, such that authorized personnel may access all drums for inspection. Proper placement will
also render subsequent IDW screening, sampling, and disposal more efficient when individual drum
removal is necessary. It is recommended that IDW drums be segregated in separate rows/areas by
matrix (i.e., soil, liquid or PPE/other).

If repeated visits are made to the project site, inspect the IDW drums to clear encroaching vegetation,
check the condition and integrity of each drum, secondary containment if applicable, check and
replace aluminum tags as necessary, and replace or restore the tarpaulin covers.

5.7.2 IDW Stockpiles

Consider IDW stockpiling only when a very large quantity of IDW will be generated. Segregate
stockpiled IDW, and inventory it by source location and depth to the extent practicable. Stockpiling
and media mixing should not be used as methods to dilute chemical concentrations in the waste. Line
stockpiles on the bottom, cover it with sturdy plastic, and locate it in areas where weather elements
(e.g., wind, rainfall runoff) will not cause migration of the waste. Never dispose of liquid IDW on a
stockpile; drum or store liquid waste in other appropriate containers. Follow applicable regulation
and guidance when sampling stockpiled waste for characterization purposes.

5.8 IDW Disposal

Various methods and requirements for onsite and offsite disposal of IDW are discussed in the
Generic IDW Disposal Plans for Hawaii and Guam (Ogden 1994, 1995) and EPA guidance (EPA
1990, 1991, 1992b). This section explains the disposal evaluation process and highlights some of the
more important requirements for onsite and offsite IDW disposal options.

IDW sampling, characterization, and disposal analysis, particularly for onsite disposal, can be
unexpectedly complex and require compliance with many different laws (that act as ARARs for
IDW management and disposal). Before preparing the IDW disposal plan, compare estimated costs
for onsite vs. offsite disposal. Offsite disposal may be more cost effective than devising and
documenting the justification for onsite disposal when the quantity of IDW is small (less than
10 drums) and/or the waste fails the initial conservative screening against conservative risk-based

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
20 of 35

criteria. Also weigh cost savings against the policy preference of the EPA and State of Hawaii
Department of Health to manage and dispose of IDW on site, when possible.

5.8.1 Onsite Disposal

In general, the EPA preference is to dispose of IDW on site when the disposal action:

•	Does not pose an unacceptable long-term risk to human health and the environment

•	Is in accordance with chemical-, location- and action-specific ARARs "to the extent
practicable" (40 CFR 300.415(i); 55 FR 8756)

•	Does not introduce contaminants into clean soil or other site media

•	Does not mobilize or significantly increase concentrations of any hazardous constituents
already present in the environment

•	Is consistent with the final remedy planned for the site

•	Takes into account any community concerns regarding waste storage and the disposal
method

Base onsite disposal options on best professional judgment and available site-specific data. For some
projects, it may be prudent to store the waste temporarily until additional site data become available
(e.g., sample analytical data, preliminary risk-assessment results, AOC delineation, and
establishment of background values). Factors to consider include, but are not limited to the
following:

•	The detected or suspected contaminants, their concentrations, and total volume of IDW

•	Media potentially affected (e.g., groundwater drinking source)

•	Background metals data for site media

•	Site access, conditions, and potential receptors

•	Current and future land use

•	Public perceptions (especially if drum storage and/or disposal takes place in open view)

•	Time limits for IDW storage

•	Potential requirements to treat waste before disposing of it on site

•	Lack of unpaved areas to disposed of waste on site

•	Potential wind, erosion, runoff, or flood conditions that might cause offsite migration of
disposed waste

•	Proximity to the ocean, surface water, or environmentally sensitive habitats

•	Natural attenuation processes

•	Need for additional utility survey before excavating to backfill waste

•	Need for land use controls required to limit exposure pathways (e.g., backfill waste, provide
permanent security around site, replant site to prevent erosion)

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
21 of 35

Protection of human health can be evaluated by comparing chemical concentrations in the waste to
the more conservative of EPA residential regional screening levels), environmental action levels, and
chemical-specific ARARs and TBC criteria. Ecological receptors can be protected by screening the
IDW against EPA ecological soil screening levels. Onsite disposal of surface and groundwater IDW
can be evaluated by initially screening against EPA tap-water PRGs, State Safe Drinking Water
Standards (maximum contaminant levels and non-zero maximum contaminant level goals), and/or
State Surface Water Quality Standards. These criteria are not always ARARs for the disposal method
or site conditions; however, they may be useful to affirmatively show that the disposal is protective.
Alternatively, the IDW may be associated with human-health and eco-risk assessment results for the
site if the onsite placement of IDW is consistent with exposure pathway assumptions made during
the risk assessment (e.g., contaminated soil might not present an unacceptable health risk at depth,
but could pose such a risk if disposed of at the ground surface).

In general, return IDW consisting of environmental media to or near its source, and return waste
generated from depth to its original depth, if possible and approved by NAVFAC in advance. Bury
all contaminated soil and water IDW to be disposed of on site below grade at a depth of at least
3 feet and cover it with clean soil to reduce the potential for future exposure to human and ecological
receptors.

Dispose of non-indigenous IDW and contaminated decontamination fluids off site. The cleaning
detergent Alconox, often used in the decontamination process, is itself non-hazardous and
biodegradable. Small quantities of clean decontamination water containing Alconox may be disposed
of to clean areas on site. If onsite disposal is appropriate for RCRA IDW, this waste should be
disposed of within the AOC to avoid the need to comply with LDRs.

IDW from several non-contiguous onsite areas may be consolidated and disposed of at one of the
areas, provided a nexus exists between the wastes generated and response projects (55 FR
8690-8691).

IDW may also be temporarily disposed of back to the AOC without detailed analysis or
documentation if the waste will be addressed with other site contamination during a future response
action and will not present a significant short-term threat to human health and the environment.

5.8.2 Offsite Disposal

If onsite disposal is not a viable option, dispose of the IDW at an appropriate offsite treatment and/or
disposal facility. Offsite transport and disposal of IDW must comply with all applicable laws and
criteria specific to the chosen disposal facility. These requirements may include, but are not limited
to the following:

•	RCRA LDRs

•	RCRA waste storage permits and time limits

•	National Pollutant Discharge Elimination System and sewer disposal criteria

•	CERCLA offsite rule

•	TSCA treatment requirements

DOT hazardous material transport packaging, manifesting, and security provisions

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
22 of 35

•	International Maritime Organization ocean transport rules

•	Certifications and training for waste transport contractors

•	State notification requirements when importing certain types of waste

The CERCLA offsite rule (40 CFR 300.440) requires that CERCLA waste be disposed of only at
facilities specifically approved by the EPA to receive such waste for treatment, storage, or disposal.
The acceptability status of a disposal facility can change quickly (e.g., if there is a release at the
facility); therefore, the CTO Manager should contact the EPA Region 9 CERCLA Offsite Rule
Coordinator no more than 60 days prior to disposal of the IDW to verify the facility's approval
status. The offsite rule applies to any CERCLA-driven remedial or removal action involving the
offsite transfer of waste containing hazardous substances regardless of the concentrations present.

RCRA hazardous waste manifests must always be signed by authorized Navy personnel. In some
cases, the Navy may authorize contractors to sign non-hazardous manifests. Navy authorization to
allow contractor signature of non-hazardous manifests shall be based upon a Navy review of the
contractor's RCRA and DOT training records. In addition, the Navy shall always be allowed the
opportunity to review/approve non-hazardous manifests and waste profiles prior to waste disposal
efforts.

Disposal of liquid IDW into the Navy sanitary sewer shall occur only if first approved by the Navy.
Requests for disposal to Navy facilities should be coordinated through the COR. Discharge to the
public sewer system is discouraged and should occur only if approved by state and local government
agencies.

5.9 Records

The CTO Manager is responsible for completing and updating the site-specific IDW drum inventory
spreadsheet and submitting it as needed, and reviewing the IDW disposal plan (IDW disposal
paperwork).

FMs and designates are responsible for documenting all IDW-related field activities in the field
notebook including most elements of the IDW drum inventory spreadsheet. The correct methods for
developing and maintaining a field notebook are presented in Procedure III-D, Logbooks.

Guidance related to preparing an IDW disposal plan (if required) is presented in the Generic IDW
Disposal Plans for Hawaii and Guam (Ogden 1994, 1995).

5.9.1 IDW Disposal Documentation

Upon receipt of analytical data from the investigation or from IDW-specific analytical data, the
generator information request form will be completed and provided to the IDW subcontractor to
begin IDW characterization. Completed IDW disposal paperwork received from the IDW
subcontractor should be reviewed for accuracy prior to submitting for Navy review.

The CTO Manager is responsible for submitting backup documentation (actual site or drum sampling
results) along with the IDW disposal paperwork to the Navy.

Navy-approved contractor personnel may sign non-hazardous waste IDW documentation. Hazardous
waste IDW documentation must be signed by an authorized Navy Environmental Coordinator.

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
23 of 35

All manifests (non-hazardous and hazardous) must be tracked, and if completed manifests (signed by
disposal facility) are not received within 30 days of initial transportation, then contractor must notify
the RPM weekly of the shipping status (e-mail is acceptable). Hazardous waste must be disposed of
within 45 days of initial transportation. If not, specific IDW transportation details must be supplied
to the Navy in order to prepare and file an exception report.

TSCA-regulated waste must be physically destroyed and or buried within 1 year of generation (date
placed in IDW drum). Disposal certificates should be provided by the waste facility to the IDW
subcontractor and Navy contractor.

Following disposal of IDW, the CTO Manager should prepare a short IDW disposal report
summarizing the disposal operation and appending any associated records (e.g., final drum log,
waste profiles, transport manifests, bills of lading, disposal facility certifications). Minimal topics to
include in the report:

•	IDW inventory and storage

•	IDW chemical screening and characterization

•	IDW transport and disposal

•	Manifests

•	Drum storage photographs

•	Site figure

6.	Health and Safety

Field Personnel shall perform work in accordance with the current (or as contractually obligated)
United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2008) and site-specific health and safety plan.

7.	References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

Environmental Protection Agency, United States (EPA). 1990. Guidance on Remedial Actions for
Superfund Sites with PCB Contamination. EPA/540/G-90-007. OSWER 9355.4-01. Office of
Solid Waste and Emergency Response. August.

	. 1991. Management of Investigation-Derived Wastes During Site Inspections. EPA-540-G-

91-009. Office of Emergency and Remedial Response. May.

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
24 of 35

	. 1992a. Guidance for Performing Site Inspections under CERCLA. EPA/540/R-92/021.

Office of Emergency and Remedial Response. September.

	. 1992b. Guide to Management of Investigation-Derived Wastes. Quick reference fact sheet.

OSWER Dir. 9345.3-03FS. Office of Solid Waste and Emergency Response. January.

	. 2007. Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, SW-846. 3rd

ed., Revision 6. Office of Solid Waste. November. On-line updates at:
http://www.epa.gov/epawaste/hazard/testmethods/sw846/online/index.htm.

	. 2009. Revisions to the PCB Q and A Manual. January.

Ogden Environmental and Energy Services Company, Inc. (Ogden). 1994. Final Generic IDW
Screening, Sampling, Analysis, and Disposal Plan for Various Guam Naval Installations. Pearl
Harbor, HI: Pacific Division, Naval Facilities Engineering Command. September.

	. 1995. Generic IDW Screening, Sampling, Analysis, and Disposal Plan for Various Hawaii

Naval Installations. Pearl Harbor, HI: Pacific Division, Naval Facilities Engineering Command.
April.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-C-2, Monitoring Well Development.

Procedure I-C-3, Monitoring Well Sampling.

Procedure I-D-l, Drum Sampling.

Procedure I-F, Equipment Decontamination.

Procedure III-D, Logbooks.

8. Attachments

Attachment I-A-6-1: IDW Drum Label
Attachment I-A-6-2: Drum Label - Aluminum Tag
Attachment I-A-6-3: Monthly IDW Drum Inventory Updates

-------
Attachment l-A-6-1
IDW Drum Label

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
27 of 35

IDW Drum Label

Contract #:



CTO #:



ACTIVITY SITE:



( - -DM

DRUM#



DATE COLLECTED



CONTENTS: (please ^ and explain)



~ Soil



|	| Water



I | Solid Waste



| | Other



PROJECT TYPE



~ RI ~ RFI ~ UST

I I Other

COMMENTS:



FOR INFORMATION CONTACT:



COR Activity/ Code:



Address:



Telephone:



-------
This page intentionally left blank

-------
Attachment l-A-6-2
Drum Label - Aluminum Tag

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
31 of 35

Drum Label - Aluminum Tag

O

CTO 91

0091-03-002
SOIL

2/29/93 Call (808) 471-0701

-------
This page intentionally left blank

-------
Attachment l-A-6-3
Monthly IDW Drum Inventory Updates

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
IDW Management

Procedure Number:
Revision Date:

Page:

i-A-6
May 2015
35 of 35

Table l-A-6-1: Monthly IDW Drum Inventory Updates

Navy Activity / Site







Origin of





Waste Generation

Expected

Actual Disposal

Name

CTO Number

Drum Number

Drum Storage

Contents (Source



Waste Volume

Date

Disposal Date

Date

(Generator Site)

(Obbb)

(xxxx-AA-DMzzz)

Location

ID#)

IDW Type

(Fill level %)

(dd-Mon-yy)

(Mon-yy)

(dd-Mon-yy)

Inspector:

Date of Inspection:

NSC Pearl Harbor/

0068

0068-LF-DM001

NSC, Bldg 7

SB-1

Soil Cuttings

100

16-Dec-92

Dec-93

N/A

Landfill



0068-LF-DM002

N/A

MW-1
MW-2
MW-3

Purge Water

75

20-Dec-92

Jul 93

26-Jul-93





0068-LF-DM003

N/A

MW-1
MW-2
MW-3

Decon. Water

95

20-Dec-92

Jul-93

26-Jul-93





0068-LF-DM004

NSC, Bldg.16

SB-1

SB-2

SB-3

SB-4

MW-1

MW-2

MW-3

PPE

50

16-Dec-92

Oct-93

N/A

NAVSTA Guam/
Drum Storage

0047

0047-DS-DM001

Hazmat Storage
Area

SB-1
SB-2

Soil Cuttings

100

18-Feb-93

Sep-93

N/A

N/A Not Applicable

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program

Procedure Number:

i-A-8

Sample Naming

Revision Date:

May 2015



Page:

1 of 5

Sample Naming

1.	Purpose

This standard operating procedure describes the naming convention for samples collected and
analyzed, and whose resulting data will be stored in the database for the United States Navy
Environmental Restoration (ER) Program, Naval Facilities Engineering Command (NAVFAC),
Pacific projects. Unique sample names are used to facilitate tracking by laboratory personnel and
project personnel, and for purposes of storing, sorting, and querying data in the database.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the Uniform Federal Policy-Quality Assurance Project Plan
(DoD 2005). As professional guidance for specific activities, this procedure is not intended to
obviate the need for professional judgment during unforeseen circumstances. Deviations from this
procedure while planning or executing planned activities must be approved and documented by the
following prime contractor representatives: the CTO Manager and the Quality Assurance (QA)
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

3.	Definitions

3.1	Chain of Custody Sample Number

The chain of custody (COC) sample number is a five-character identification number that is used by
the laboratory and project personnel for tracking purposes. A unique COC sample number must be
used for each sample collected from a particular location at a particular time. It is useful for the first
two characters to be letters unique to a particular site or project, while the remaining three characters
may be digits from 001 to 999 (e.g., AA001). The COC sample number is the only identifier that
should be presented to the laboratory.

3.2	Sample Identification Number

The sample identification number is a unique multi-alpha, multi-numeric identifier that is used by the
field team to associate sampling results to the particular sampling location, sample type, number of
times the location has been sampled, and depth. To avoid potential bias in sample analysis, the
sample identifier is not provided to the laboratory. The sample identification number shall be
recorded in the field logbook concurrently with the COC sample number.

4.	Responsibilities

The prime contractor CTO Manager shall ensure that a proper sample naming convention is
identified in the field sampling plan. The Field Quality Control (QC) Supervisor or other
field-sampling leader shall ensure that the sample naming convention is implemented. The laboratory
coordinator, CTO Manager, and/or other designated personnel shall ensure on a daily basis that
unique, appropriate COC sample numbers and sample identifiers have been assigned. The prime

-------
NAVFAC Pacific ER Program
Sample Naming

Procedure Number:
Revision Date:
Page:

i-A-8
May 2015
2 of 5

contractor QA Manager or Technical Director is responsible for ensuring overall compliance with
this procedure.

The prime contractor Technical Director will designate one person in each office (e.g., the laboratory
coordinator) to track site designations used in the COC sample number.

5. Procedures

A COC sample number and sample identifier shall be assigned as described below. It is critical that
each sample name have a unique COC sample number and sample identifier; otherwise, data cannot
be properly stored and tracked in the database.

5.1 COC Sample Number

Use the following format for the COC sample number:

a = A letter indicating the office managing the CTO
b = A letter indicating the project or site, for example
A = first site
B = second site
C = third site, etc.
ccc = Chronological number, for example

001	= first sample from the site

002	= second sample from the site
105 = 105th sample from the site

Field QC samples should be included in this chronological sequence

For example, the 23rd sample from the Carpentry Shop Dip Tank site (assigned project "A" for b
above; the office will be assigned "D") being investigated would be referred to as "DA023." This
might be a soil sample, water sample, trip blank, equipment blank, field duplicate, or other sample
type. Using this COC sample number, the samples will be submitted to the laboratory "blind," that
is, the laboratory should not know whether each sample received is a site or field QC sample.

If a sample is lost during shipping, the replacement sample must be assigned a new COC sample
number. If different containers for the same sample are shipped on different days, a new COC
sample number must be assigned.

When numbering reaches the letter Z, the 26th site, it may begin with a new first letter "a," which
must be coordinated with the prime contractor QA Manager or Technical Director and Coordinator
or designee to ensure that it has not been used by another CTO.

abccc

Where:

-------
NAVFAC Pacific ER Program
Sample Naming

Procedure Number:
Revision Date:
Page:

i-A-8
May 2015
3 of 5

Alternatively, the "ab" designators can serve to identify a unique project field, such as "RH" for the
Red Hill site.

5.2 Sample Identification Number

The following format is provided as a suggested guidance. Individual site objectives may necessitate
variations to the suggested guidance. Coordinate with the prime contractor QA Manager or
Technical Director when considering deviating from this guidance.

AA-bbcc-dee-Dff.f

Where:

AA =

Designates the site identification

bb =

Sample type and matrix (see Table I-A-8-1)

cc =

Location number (e.g., 01, 02, 03)

d =

Field QC sample type (see Table I-A-8-2)

ee =

Chronological sample number from a particular sampling location (e.g., 01, 02, 03)

D =

The letter "D" denoting depth

ff.f =

Depth of sample in feet bgs (to the measured decimal place). For field blanks, trip



blanks and equipment blanks, the depth field will contain the month and date of

collection.

For example, the first subsurface soil sample collected from the Foundry Building (FB) borehole
location four at a depth of 10 feet would be designated "FB-BS04-S01-D10.0." These characters will
establish a unique sample identifier that can be used when evaluating data.

Table I-A-8-1 presents the character identifiers to be used in the sample and matrix portion of the
sample identification number. In all cases, the second letter indicates the sample matrix. Note grab,
composite, and undisturbed sample designations in the field logbook.

Table l-A-8-1: Sample Type and Matrix Identifiers

Identifier

Sample Type

Matrix

SS

Surface Soil

Soil

IS

Surface Soil (ISM)

Soil

IB

Subsurface Soil (ISM)

Soil

BS

Subsurface Soil

Soil

BG

Subsurface Soil (Geotechnical)

Soil

SD

Sediment

Sediment

GW

Groundwater

Water

SW

Surface Water

Water

FP

Free Product

Oil

WQ

Water Blanks

Water

SG

Soil Gas

Soil gas

CC

Concrete Chips

Concrete

-------
NAVFAC Pacific ER Program
Sample Naming

Procedure Number:
Revision Date:
Page:

i-A-8
May 2015
4 of 5

Identifier

Sample Type

Matrix

WS

Waste (IDW)

Soil

WW

Waste (IDW)

Water

IDW investigation-derived waste
ISM incremental sampling methodology

Table I-A-8-2 describes the field QC designator types. These field QC designators clarify the type of
sample collected.

Table l-A-8-2: Field QC Sample Type Identifiers

Identifier

QC Sample Type

Description

S

Normal (Primary) Sample

All non-field QC samples

D

Duplicate

Collocate (adjacent liners)

R

Triplicate

Replicate

E

Equipment Rinsate

Water

B

Field Blank

Water

T

Trip Blank

Analytical-laboratory-prepared sample -Water

M

Trip Blank

Analytical-laboratory-prepared sample - Methanol

L

Batch Test Sample

Batch Test Leaching Model Sample

P

Blind Spike

Performance testing sample

6.	Records

Sample identifiers (and COC sample numbers, if appropriate) shall be identified in advance if the
exact numbers of samples to be collected are known; these numbers may be listed on a spreadsheet
along with requested analyses to be used as a reference by field sampling personnel.

The COC/analytical request form must be used to track all sample names. Copies of each COC form
shall be sent daily to the CTO Laboratory Coordinator and with the samples to the analytical
laboratory. An example of a COC form is included as Attachment III-E-2 of Procedure III-E, Record
Keeping, Sample Labeling, and Chain-of-Custody.

In the field, personnel shall record in the field logbook the COC sample number of each sample
collected, as well as additional information, such as the sampling, date, time, and pertinent
comments.

7.	Health and Safety

Not applicable.

8.	References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

-------
NAVFAC Pacific ER Program
Sample Naming

Procedure Number:
Revision Date:
Page:

i-A-8
May 2015
5 of 5

Procedure III-E, Record Keeping, Sample Labeling, and Chain-of-Custody.

9. Attachments

None.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
1 of 34

Soil Sampling

1.	Purpose

This section sets forth the standard operating procedure for soil sampling (surface samples, trench
samples, and boring samples) to be used by United States (U.S.) Navy Environmental Restoration
(ER) Program, Naval Facilities Engineering Command (NAVFAC), Pacific personnel.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the most recent version of the Uniform Federal Policy-Quality
Assurance Project Plan (UFP QAPP) Part 1 (DoD 2005a), 2A (DoD 2012), and 2B (2005b), as well
as the DoD Quality Systems Manual (DoD 2013). As professional guidance for specific activities,
this procedure is not intended to obviate the need for professional judgment during unforeseen
circumstances. Deviations from this procedure while planning or executing planned activities must
be approved and documented by the following prime contractor representatives: the CTO Manager
and the Quality Assurance (QA) Manager or Technical Director. A Navy project representative
(i.e., Remedial Project Manager or QA Manager) shall also concur with any deviations.

3.	Definitions

None.

4.	Responsibilities

The prime contractor CTO Manager is responsible for ensuring that these standard soil sampling
procedures are followed during projects conducted under the NAVFAC Pacific ER Program, and
that they are conducted or supervised by a qualified individual. A qualified individual for subsurface
sampling is defined as a person with a degree in geology, hydrogeology, or geotechnical/civil
engineering with at least 1 year of experience in the supervision of soil boring construction. A
qualified individual for trenching, excavation (e.g., pit), or surface sampling supervision is one who
has sufficient training and experience to accomplish the objectives of the sampling program. The
CTO Manager shall also ensure that a qualified person, as defined in Procedure I-E, Soil and Rock
Classification, conducts soil classification during all types of soil sampling. The CTO Manager is
responsible for ensuring that all personnel involved in sampling and/or testing shall have the
appropriate education, experience, and training to perform their assigned tasks as specified in Chief
of Naval Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
2 of 34

The Field Manager is responsible for ensuring that all project field staff follow these procedures.

Field sampling personnel are responsible for the implementation of this procedure.

5. Procedures

5.1	Considerations For Munitions and Explosives of Concern

Potential Munitions and Explosives of Concern (MEC) hazards may be encountered in any area
formerly or currently occupied or used by the Department of Defense (DoD). MEC hazards may
occur on the ground surface, in the subsurface, and within bodies of water, and may not always be
readily observable, or identifiable. As a result, whether or not munitions-related activities ever
occurred on the specific work area or within waters in which Navy operations/activities will take
place, special care should always be taken when conducting field operations, especially intrusive
activities, in the event that MEC may be encountered.

If the site is currently recognized as belonging in the Military Munitions Response Program and has
a current, Naval Ordnance Safety and Security-accepted, site-specific Explosives Safety Submission
(ESS) (per DON 2010), then field activities, especially intrusive activities, shall adhere to the safety
procedures outlined within the ESS.

If suspected MEC is encountered on an active DoD installation, immediately notify your supervisor,
DoD Point of Contact, and installation Point of Contact, who will contact and facilitate military
Explosive Ordnance Disposal response.

5.2	Subsurface Soil Sampling

The purpose of subsurface soil sampling is to acquire accurate, representative information about
subsurface materials penetrated during drilling or trenching. This is accomplished by logging
lithologic information, classifying lithologic materials, and collecting lithologic samples for analysis
using geotechnical or chemical methods.

5.2.1	Inspection of Equipment

The collection of reliable samples of subsurface materials depends partly on the types of samples that
can be collected when using various subsurface exploration techniques. These procedures are
described in Section 5.2. In all cases, the equipment shall be inspected prior to commencement of
drilling for signs of fluid leakage, which could introduce contaminants into the soil. If, at any time
during subsurface exploration, fluid is observed leaking from the rig, operations shall cease and the
leak shall be immediately repaired or contained. All soil and other materials affected by the leak will
be collected, containerized, and labeled for proper disposal (Procedure I-A-6, Investigation-Derived
Waste Management).

5.2.2	Preparation of Site

Proper preparation of the site prior to the commencement of subsurface exploration is essential for
smooth drilling operations. It is required to protect the health and safety of site personnel. First, the

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
3 of 34

site shall be inspected to ensure that there are no overhead hazards that could affect subsurface
exploration. Then, all subsurface sampling locations shall be assessed using geophysical methods to
identify subsurface utilities or hazards. If possible, the area shall be excavated by hand to a depth of
2 to 3 feet before beginning drilling. If surface or shallow samples are required, it is suggested that
the hand excavation be done as close to the actual subsurface exploration as possible. The drill rig
must have a means to guard against employee contact with the auger (e.g., guard around the auger;
barricade around the perimeter of the auger; electronic brake activated by a presence-sensing
device). All members of the field crew shall know the location of the kill switch, which must be
readily accessible, for the equipment.

The equipment shall be situated upwind or side-wind of the borehole. The area surrounding, and in
the vicinity of, the borehole shall be covered with plastic, including the area where cuttings are
placed into 5 5-gallon drums and the equipment decontamination area. The required exclusion zones
shall be established by using plastic tape or cones to designate the various areas.

5.2.3	Equipment Decontamination

To avoid cross-contamination, all sampling equipment utilized for borehole drilling and soil
sampling that may potentially come into contact with environmental samples shall be thoroughly
decontaminated as described in Procedure I-F, Equipment Decontamination. All sampling tools shall
be decontaminated between each sampling event and between each borehole or trench. At a
minimum, all equipment shall be steam-cleaned or undergo the wash-and-rinse process. All
wash-and-rinse water shall be collected, containerized, and labeled for proper disposal. Clean
equipment (e.g., augers and samplers) shall be protected from contact with contaminated soils or
other contaminated materials prior to sample collection. Equipment shall be kept on plastic or
protected in another suitable fashion. After a borehole is completed, all augers and contaminated
downhole equipment shall be stored on plastic sheeting.

5.2.4	Handling of Drill Cuttings

All soil cuttings from borehole drilling shall be placed into 55-gallon U.S. Department of
Transportation (DOT)-approved drums or other appropriate containers, such as a roll-off bin. The
containerized cuttings shall be stored in a centralized area pending sample analysis to determine their
final disposition. The procedure on investigation-derived waste (IDW) (see Procedure I-A-6,
Investigation-Derived Waste Management) details drum handling and labeling procedures.

5.3 Subsurface Soil Sample Collection Methods

Table I-B-l-1 describes the characteristics of the sampling methods for the drilling techniques
frequently used for soil borings and monitoring well installation, as described in Procedure I-C-l,
Monitoring Well Installation and Abandonment. The split-spoon sampling method is the most
commonly used soil sampling technique. However, in certain circumstances, other methods may
have to be used to obtain optimal soil sampling results.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
4 of 34

Sampling and handling procedures for samples submitted for volatile organic compound (VOC)
analyses are provided in Attachment I-B-l-1. Considerations when using incremental sampling (IS)
methods are provided in Attachment I-B-l-1.

Table l-B-1 -1: Characteristics of Common Subsurface Formation-Sampling Methods

Type of
Formation

Sample
Collection
Method

Sample
Quality

Potential for Continuous
Sample Collection?

Samples Suitable for
Analytical Testing?

Discrete Zones
Identifiable?

Unconsolidated

Bulk Sampling
(Cuttings)

Poor

No

No

No



Thin Wall

Good

Yes

Yes

Yes



Split Spoon

Good

Yes

Yes

Yes



Trench

Good

No

Yes

Yes



Core Barrels

Good

Yes

Yes

Yes

Consolidated

Cuttings
(direct rotary)

Poor

No

No

No



Core Barrels

Good

Yes

Yes

Yes

The following text describes the primary soil sampling methods used for the NAVFAC Pacific ER
Program.

5.3.1 Split-Spoon Samples

Split-spoon sampling is usually used in conjunction with the hollow-stem or solid-stem auger drilling
method and can be used for sampling most unconsolidated and semi-consolidated sediments. It is
used less frequently for air and mud rotary, and casing drive methods. It cannot normally be used to
sample bedrock, such as basalt, limestone, or granite. The method can be used for highly
unconsolidated sands and gravels if a stainless-steel sand catcher is placed in the lower end of the
sampler.

The split-spoon sampler consists of a hardened metal barrel, 2 to 3 inches in diameter (2 to
2.5 inches inner diameter) with a threaded, removable fitting on the top end for connection to the
drill rods and a threaded, removable "shoe" on the lower end that is used to penetrate the formation.
The barrel can be split along its length to allow removal of the sample.

The following steps are required to obtain a representative soil sample using a split-spoon sampler:

Advance the borehole by augering until the top of the desired sampling interval is reached.
Then withdraw the drill bit from the hollow-stem augers.

Equip the sampler with interior liners that are composed of materials compatible with the
suspected contaminants if samples are to be retained for laboratory analytical analysis.
Generally, these liners consist of brass or stainless steel and are slightly smaller than the
inner diameter of the sampler. It is recommended to use stainless-steel liners rather than

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
5 of 34

brass if samples are to be analyzed for metals. Always evaluate the composition of the liners
with respect to the types of contaminants that are suspected.

Attach the properly decontaminated split-spoon sampler (equipped with liners) either to the
drill rods or to a cable system and lower it to the bottom of the borehole through the augers.

Drive the sampler into the formation by either a manual or automatic hammer (usually a
140-pound weight dropped through a 30-inch interval). Record the number of blows required
to drive the sampler at 6-inch intervals in the boring log since blow counts provide an
indication of the density/compaction of the soils being sampled. The field geologist,
hydrogeologist, or geotechnical engineer shall carefully observe the internal measuring
technique of the driller and keep track of sampling materials to ensure the accurate location
of samples. Continuous samples can be collected with the split-spoon method by augering or
drilling to the bottom of the previously sampled interval and repeating the operation.
Whether continuous or intermittent, this collection method disturbs samples and cannot be
used for certain geotechnical tests that require undisturbed samples.

Bring the split-spoon sampler to ground surface and remove it from the drill rods or cable
system following sample acquisition. Loosen the upper and lower fittings and take the
sampler to the sample handling area. At the sample handling area, remove the fittings, split
the barrel of the sampler, and remove one side of the sampler. At this time, it is important to
observe and record the percentage of sample recovery.

Liners—Sampler liners can be used to collect and store samples for shipment to laboratories, for
field index testing of samples, and for removing samples from solid barrel type samplers. Liners are
available in plastic, Teflon, brass, and stainless steel. Other materials can be used as testing needs
dictate. Liners are available in lengths from 6 inches (152.4 millimeters) to 5.0 feet (1.53 meters).
Liner material selection often is based on the chemical composition of liner/soil to minimize sample
reaction with liner. Most liner use is short-term as samples are subsampled and preserved
immediately on site. Teflon may be required for mixed wastes and for long-term storage. Liners
generally are split in the field for subsampling. Individually split liners are available in some sizes
for field use. The liner should have a slightly larger inside diameter than the soil specimen to reduce
soil friction and enhance recovery. When a slightly oversized liner is used, the potential for air space
exists around the sample. Certain chemical samples may be affected by the enclosed air. Liners with
less tolerance may be required and a shortened sample interval used to reduce friction in the liner.
Metal liners can be reused after proper cleaning and decontamination. Plastic liners should be
disposed of properly after use (ASTM 2005).

Immediately remove the liners containing the soil samples from the sampler. Generally, the
lowermost liner is considered the least disturbed and shall be retained as the analytical laboratory
sample. However, in certain circumstances (such as with the use of a sand catcher), other liners may
be more appropriate for retention as the laboratory sample. If liners containing the sample material
are to be submitted to the laboratory, then cover the ends of the sample liner to be retained as the
analytical laboratory sample with Teflon film and sealed with plastic caps. While currently not

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
6 of 34

preferred by the State of Hawaii, if liners are submitted, the laboratories should be instructed to
prepare the soil from the liner as an incremental sample to prevent biasing the results that can occur
when discretely collecting the analytical volume. The site geologist, hydrogeologist, or geotechnical
engineer shall observe the ends of the liner destined for analytical sampling and describe the physical
nature of the sample (e.g., soil or rock type, grain size, color, moisture, as indicated in Procedure I-E,
Soil and Rock Classification.) Then label the sample according to Procedure III-E, Record Keeping,
Sample Labeling, and Chain-of-Custody, and immediately place it on ice in a cooler as described in
Procedure III-F, Sample Handling, Storage, and Shipping.

Collect split-spoon soil samples submitted for VOC analysis using the procedure found in
Attachment I-B -1 -1.

Collect split-spoon soil samples submitted for non-VOC analysis using the IS procedure
found in Attachment I-B-l-1

Any remaining liners collected from the sample can then be used for other purposes, such as
providing a duplicate sample for field quality control or material for lithologic logging.
These samples can also be used for headspace analysis as described in Section 5.4.

Conduct lithologic logging of each sample in accordance with Procedure I-E, Soil and Rock
Classification, and enter each sample into the boring log presented in Figure I-B-l-1. In
most instances, an additional liner full of material is available for this purpose. Check to
ensure that all liners contain similar material. If an extra liner full of material is not
available, then log by collecting the extra material present in the end of the sampler shoe.
Make a comparison to the material visible at the end of the sample liner destined for
laboratory analysis to ensure that the entire sample consists of similar material. If not, then
describe the different material to the extent possible by relating it to similar material that was
encountered previously.

If VOCs are suspected to be present, screen the sample with an organic vapor monitor
(OVM) or equivalent, and collect headspace samples according to Section 5.4.

Decontaminate all sampling equipment prior to each use according to Procedure I-F,

Equipment Decontamination.

5.3.2 Thin-Wall Samples

The thin-wall or Shelby tube sampler is usually used in conjunction with the hollow-stem and solid-
stem auger drilling methods and is most useful when sampling clay- and silt-rich sediments. It can
also be used with air and mud rotary and casing drive drilling techniques. It is amenable only to
lithologies that are relatively soft and, in some cases, is not capable of penetrating hard clays or
compacted sands. In addition, samples of unconsolidated sands cannot normally be acquired because
they cannot be retained within the sampler, although a sand catcher can be utilized, in some cases,
with moderate success.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
7 of 34

The thin-wall sampler often consists of a single thin tube that is 3 to 4 inches in outer diameter and
1 to 3 feet in length. The upper end of the sampler has a solid metal section with a fitting for drill
rods. There is no fitting for the lower end of the sampler, and it is usually open to allow sample
acquisition; however, when sampling in poorly consolidated materials, a sand catcher may be placed
in the lower end to ensure retention of the sample.

The following steps are required to obtain a representative soil sample using a thin-wall sampler:

Advance the borehole by augering or drilling until the top of the desired sampling interval is
reached. Then withdraw the drill bit from the hollow-stem augers.

Place the sampler on the end of the drill rods and lower it to the bottom of the borehole.

Instead of driving the sampler, use the hydraulic apparatus associated with the kelly bar on
the drilling rig to press the sampler into the undisturbed formation. The thin-wall sampler
may lack sufficient structural strength to penetrate the materials, in which case another
sampling technique may be required. The samples obtained using this method cannot be
used for certain geotechnical tests where undisturbed samples are required.

Thin-wall samples submitted for VOC analysis must be collected using the procedure found
in Attachment I-B -1 -1.

Following sample acquisition, bring the thin-wall sampler to the ground surface, remove it
from the drill rods, and take it to the sample handling area.

Immediately cover the ends of the sample with Teflon film and sealed with plastic caps if the
sample is to be retained as a laboratory sample. Then label the sample according to
Procedure III-E, Record Keeping Sample Labeling, and Chain of Custody and immediately
place it on ice in a cooler. Extrude the sample from the sampler and inspect it if the sample is
to be used only for lithologic logging.

Conduct lithologic logging of each sample in accordance with Procedure I-E, Soil and Rock
Classification and enter each sample into the boring log presented in Figure I-B-l-1. If the
sample is contained in a sleeve, observe the ends of the sample in the sleeve to assess
lithologic and stratigraphic characteristics.

If VOCs are suspected to be present, screen the sample with an OVM or equivalent, and
collect headspace samples according to Section 5.4.

Decontaminate all sampling equipment prior to each use according to Procedure I-F,

Equipment Decontamination.

5.3.3 Cores

A core barrel is often used to obtain core samples from harder lithologic materials, such as basalt, granite,
and limestone, in instances where undisturbed samples are required for geotechnical testing, and in cases
where completely continuous sampling is required. Complete recovery of samples during coring is often
difficult when sampling unconsolidated and semi-consolidated lithologies, such as clays, silts, and sands.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
8 of 34

Field Log of Boring

BORING NUMBER

PROJECT NAME

PROJECT NUMBER

ELEVATION AND DATUM

LOCATION

DRILLING COMPANY

DRILLER

DATE AND TIME STARTED

DATE AND TIME COMPLETED

DRILLING EQUIPMENT

DRILLING METHOD

COMPLETION DEPTH

TOTAL NO. OF SAMPLES

SIZE AND TYPE OF BIT

HOLE DIAMETER

NO. OF
SAMPLES

BULK

SS

DRIVE

PITCHER

DRILLING FLUID

DRILLING ANGLE

WATER
LEVEL

FIRST

AFTER HOURS

SAMPLE HAMMER

TYPE DRIVING WT. DROP

HYDROGEOLOGIST/DATE

CHECKED BY/DATE

LITHOLOGY

DEPTH

(FEET)

s

A
M
P
L
E
S

R
E
C
0

V
E
R

Y

BC
LO
0 U
WN
T

DESCRIPTION

uses

SYMBOL

ESTIMATED
PERCENT OF

COMMENTS

GR

SA

Fl















































































































































































































































































































































































Figure l-B-1-1: Field Log of Boring

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
9 of 34

ASTM International (ASTM) has standardized rock coring methods (D-2113) (ASTM 2006). Several
standardized core sizes for bits, shells, and casings have been established (e.g., RX, NX, SW).
Table I-B-l-2 summarizes the various size standards for core barrels and bits.

Table l-B-1 -2: Standard Core Barrel Sizes (in inches)

Description

RXor
RW

EX or
EW

AX or
AW

BX or
BW

NX or
NW

HX or
HW

PX or
PW

SX or
SW

UX or
UW

ZXor
ZW

Bit Set Normal I.D.

0.750

0.845

1.185

1.655

2.155

3.000

—

—

—

—

Bit Set Normal and
Thin-wall O.D.

1.160

1.470

1.875

2.345

2.965

3.890

—

—

—

—

Bit Set Thin-wall. I.D

0.735

0.905

1.281

1.750

2.313

3.187

—

—

—

—

Shell Set Normal and
Thin-wall O.D.

1.175

1.485

1.890

2.360

2.980

3.907

—

—

—

—

Casing Bit Set I.D.

1.000

1.405

1.780

2.215

2.840

3.777

4.632

5.632

6.755

7.755

Casing Bit Set and
Shoe O.D.

1.485

1.875

2.345

2.965

3.615

4.625

5.650

6.780

7.800

8.810

I.D. Inner Diameter
O.D. Outer Diameter

The selection of the most practical core barrel for the anticipated bedrock conditions is important.
The selection of the correct drill bit is also essential to good recovery and drilling production.
Although the final responsibility of bit selection usually rests with the drilling contractor, there is a
tendency in the trade to use "whatever happens to be at hand." The selection of the diamond size, bit
crown contour, and number of water ports depends upon the characteristics of the rock mass. The use
of an incorrect bit can be detrimental to the overall core recovery. Generally, fewer and larger
diamonds are used to core soft formations, and more numerous, smaller diamonds, which are
mounted on the more commonly used semi-round bit crowns, are used in hard formations. Special
impregnated diamond core bits have been developed recently for use in severely weathered and
fractured formations where bit abrasion can be very high.

Core barrels are manufactured in three basic types: single tube, double tube, and triple tube. These
basic units all operate on the same principle of pumping drilling fluid through the drill rods and core
barrel. This is done to cool the diamond bit during drilling and to carry the borehole cuttings to the
surface. A variety of coring bits, core retainers, and liners are used in various combinations to
maximize the recovery and penetration rate of the selected core barrel.

The simplest type of rotary core barrel is the single tube, which consists of a case hardened, hollow
steel tube with a diamond drilling bit attached at the bottom. The diamond bit cuts an annular groove,
or kerf, in the formation to allow passage of the drilling fluid and cuttings up the outside of the core
barrel. The single tube core barrel cannot be employed in formations that are subject to erosion,
slaking, or excessive swelling, as the drilling fluid passes over the recovered sample during drilling.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
10 of 34

The most popular and widely used rotary core barrel is the double tube, which is basically a single
tube barrel with a separate and additional inner liner that is available in either a rigid or swivel type
of construction. In the rigid types, the inner liner is fixed to the outer core barrel so that it rotates
with the outer tube. In contrast, the swivel type of inner liner is supported on a ball-bearing carrier,
which allows the inner tube to remain stationary, or nearly so, during rotation of the outer barrel. The
sample, or core, is cut by rotation of the diamond bit. The bit is in constant contact with the drilling
fluid as it flushes out the borehole cuttings. The addition of bottom discharge bits and fluid control
valves to the core barrel system minimizes the amount of drilling fluid and its contact with the
sample, which further decreases sample disturbance.

The third and most recent advancement in rotary core barrel design is the triple tube core barrel,
which adds another separate, non-rotating liner to the double tube core barrel. This liner, which
retains the sample, consists of a clear plastic solid tube or a split, thin metal liner. Each type of liner
has its distinct advantages and disadvantages; however, they are both capable of obtaining increased
sample recovery in poor quality rock or semi-cemented soils, with the additional advantage of
minimizing sample handling and disturbance during removal from the core barrel.

The rotary core barrels that are available range from 1 to 10 inches in diameter, and the majority may
be used with water, drilling mud, or air for recovering soil samples. Of the three basic types of core
barrels, the double tube core barrel is most frequently used in rock core sampling for geotechnical
engineering applications. The triple tube core barrel is used in zones of highly variable hardness and
consistency. The single tube is rarely used because of its sample recovery and disturbance problems.

Coring to obtain analytical samples requires only filtered air as the drilling fluid. The core barrel
operates by rotating the outer barrel to allow the bit to penetrate the formation. The sample is
retained in the inner liner, which in most samplers does not rotate with the outer barrel. As the outer
barrel is advanced, the sample rises in the inner liner. In general, a secondary liner consisting of
plastic or metal is present within the inner liner to ensure the integrity of acquired samples.

Obtain soil or rock core samples with a core barrel or a 5-foot split-spoon core barrel using the
following procedure:

Drill the core barrel to the appropriate sampling depth. It is important to use only clean,
filtered air (i.e., particulate- and petroleum-free) as drilling fluid while coring to obtain
samples for laboratory analysis. If necessary, distilled water may be added through the
delivery system of the coring device by the driller, provided that the drilling returns cannot
be brought to the surface by air alone.

Retrieve the core barrel from the hole. Use care to ensure that the contents of the core barrel
do not fall out of the bottom during withdrawal and handling.

Open the core barrel by removing both the top and bottom fittings. Then remove the sample
within the inner liner from the core barrel and take it to the sample handling area.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
11 of 34

Conduct lithologic logging of each sample in accordance with Procedure I-E, Soil and Rock
Classification, and enter each sample into the boring log presented in Figure I-B-l-1.

If VOCs are suspected to be present, screen the sample with an OVM or equivalent, and
collect headspace samples according to Section 5.4.

Collect core samples submitted for VOC analysis using the procedure found in Attachment I-B-l-1.

If rock core samples are to be recovered for analytical laboratory or geotechnical analyses,
the core barrel will either be lined with a sample container (e.g. stainless steel or acrylic
liner), or the samples will be transferred to an appropriate sample container (e.g. stainless
steel / acrylic liner, glass jar). Samples collected or placed in stainless steel or acrylic liners
shall have the ends of the liners covered with Teflon film and sealed with plastic end caps.
The sample containers shall be labeled in accordance with Procedure III-E, Record Keeping,
Sample Labeling, and Chain-of-Custody, and Procedure III-F, Sample Handling, Storage,
and Shipping, and immediately placed on ice in a cooler.

Place the samples in core boxes if samples are to be catalogued and stored. Affix the CTO
number; site name; borehole number; start depth; end depth; date; and name of the geologist,
hydrogeologist, or geotechnical engineer to the core box. Store the samples in a clean, dry
area on site during the duration of field sampling; samples shall not be brought back to the
office or equipment storage area. Document proper disposal at the completion of field
sampling.

Decontaminate all sampling equipment prior to each use according to Procedure I-F,

Equipment Decontamination.

5.3.4 Bulk Samples

The term "bulk sample" represents a sample collected from borehole cuttings either from the hollow-
stem auger flights or the discharge of any of the rotary or cable tool drilling techniques. This type of
sample is useful for describing soils or consolidated materials, where no undisturbed samples
representative of a specific depth are being collected. It should be noted that this type of sample is
generally considered to be the least acceptable of the types of samples previously described in this
section and shall be used only when detailed lithologic data are not needed.

Handling and lithologic logging of bulk samples should be performed in a manner consistent with
that used for split-spoon samples. An estimate of the depth (or range of depths) from which the
sample was obtained, and date and time of collection should be recorded on the boring log. Samples
are usually collected every 5 feet, preferably at several different times during a 5-foot drilling run so
that lithologic variations occurring over the drilling interval can be noted. Rock fragments commonly
range in size from 1/16 to 1/2 inch, with many fragments larger than 1/4 inch. Larger fragments can
often be obtained with reverse circulation rotary drilling. Rotary-tool samples usually contain some
caved materials from above and, when drilling with mud or water rotary, the cuttings may contain
soil and rock recirculated by the mud/water pump; therefore, care must be exercised when
interpreting lithologic logs completed using data from this type of sample.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
12 of 34

Because the collection of samples at the surface lags behind the actual drilling of a given lithologic
bed at depth, the samples usually represent a depth less than that of the current depth of the drill bit.
The amount of lag may be significant in deeper boreholes, but can be eliminated by collecting
samples after circulating for a period of time sufficient to permit the most recently drilled materials
to reach the surface.

5.3.5	Borehole Abandonment

Following completion of soil sampling, the borehole shall be properly abandoned unless a
monitoring well is to be installed. Abandonment shall occur immediately following acquisition of the
final sample in the boring and shall consist of the placement of a bentonite-cement grout from the
bottom of the boring to within 2 feet of ground surface. The grout mixture shall consist of a mix of 7
to 9 gallons of water per 94-pound bag of Portland Type I or II cement with 3 to 5 percent by weight
of powdered bentonite. Other commercial products such as Volclay are also acceptable with
approval of the CTO Manager and QA Manager or Technical Director. The bentonite-cement grout
shall be placed in one continuous pour from the bottom of the boring to within at least 0.5 foot to
2 feet of ground surface through a tremie pipe or hollow-stem augers. Additional grout may need to
be placed if significant settlement occurs. The remaining portion of the boring can be filled with
topsoil.

5.3.6	Trenching and Pit Sampling

Trenching is used in situations where the depth of investigation generally does not exceed 10 to
15 feet and is most suitable for assessing surface and near-surface contamination and geologic
characteristics. In addition, trenching allows detailed observation of shallow subsurface features and
exposes a wider area of the subsurface than is exposed in borings. Pit sampling is typically
conducted in conjunction with a removal or remedial action.

A backhoe is usually used to excavate shallow trenches to a depth of no greater than 15 feet.
Front-end loaders or bulldozers are used when it is not possible to use a backhoe; for example, when
materials lack cohesion or are too stiff, or the terrain is too steep for a backhoe. Larger excavations
(i.e., pits) may require additional equipment as described in the CTO work plan (WP) or equivalent
document.

Typically, trenches have widths of one to two backhoe buckets and range in length from 5 to 20 feet,
although larger trenches can be dug depending on the objectives of the study. Pits will vary in size
depending upon the scope of the removal/remedial action. Soils removed from the trench/pit shall be
carefully placed on plastic sheeting or other appropriate materials in the order of removal from the
trench or excavation. The shallow excavated materials can be placed on one side of the
trench/excavation and deeper materials on the other side to allow better segregation of shallow and
deep materials.

Soil sampling locations within each trench or pit shall be chosen on the basis of visual inspection and
any VOC screening results. Samples shall be collected from either the sidewalls or the bottom of the
trenches/excavations. Soil sampling should be conducted outside the trench/excavation, and

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
13 of 34

personnel generally should not enter a trench or pit if there is any other means (e.g., backhoe
buckets, hand augers, shovels, or equivalent) to perform the work. If entry is unavoidable, then a
competent person shall first determine acceptable entry conditions including sloping, shoring, and air
monitoring requirements, personal protective equipment (PPE), and inspections. In addition, the site-
specific health and safety plan must be amended to include applicable requirements of 29 Code of
Federal Regulations (CFR) 1910.146.

Equipment used for trench/pit sampling may include hand augers, core samplers (slide hammer),
liners inserted manually into the soil, or hand trowels. In addition, samples may be obtained directly
from the trench or from the backhoe bucket. All samples shall be properly sealed and labeled
according to Procedure III-E, Record Keeping, Sample Labeling, and Chain-of-Custody, and
immediately placed on ice in a cooler as indicated in Procedure III-F, Sample Handling, Storage, and
Shipping. Sample locations and descriptions shall be described and recorded on the field trench/pit
log.

Trench or pit samples submitted for VOC analysis must be collected using the procedure found in
Attachment I-B -1 -1.

The exposed materials shall be observed for lithologic and contaminant characteristics following
completion of the excavation activities. Detailed mapping of the exposed walls of the trench shall be
conducted, although in no instance shall personnel enter a trench without first determining
acceptable entry conditions including sloping, shoring, and air monitoring requirements, PPE, and
inspections as defined in 29 CFR 1910.146. A useful mapping technique for extremely long trenches
or large pits is to examine the vertical profile of the excavation at horizontal intervals of 5 to 10 feet,
in a manner similar to the method typically used for preparation of a geologic cross-section using
soil borings. Field observations shall be noted in the field logbook and described in detail on a
trench/pit log. An example of a field trench/pit log is presented in Figure I-B-l-2. The lithologic
description shall include all soil classification information listed in Procedure I-E, Soil and Rock
Classification. A cross-section of the trench or pit should also be included on the field trench/pit log.
Photographs of the trench/pit are also an excellent way to document important subsurface features.

During backfilling of the excavation, the materials excavated from the greatest depth should be
placed back into the excavation first. Lithologic materials should be replaced in 2- to 4-foot lifts and
recompacted by tamping with the backhoe bucket. For certain land uses or site restoration, more
appropriate compaction methods may be required. These methods shall be described in the CTO WP
and design documents. The backfilled trench/pit shall be capped with the original surface soil. If
materials are encountered that cannot be placed back in the excavation, they should be placed either
in DOT-approved open-top drums or placed on and covered with visqueen or equivalent material and
treated as IDW in accordance with Procedure I-A-6, Investigation-Derived Waste Management.

5.4 Surface Soil Sampling

All surface soil samples shall be accurately located on field maps in accordance with Procedure I-I,
Land Surveying. Detailed soil classification descriptions shall be completed in accordance with

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
14 of 34

Procedure I-E, Soil and Rock Classification and recorded on the surface and shallow soil sample log
(Figure I-B-l-3).

In general, surface soil samples are not to be analyzed for VOCs unless there is sufficient evidence to
suggest the presence of such compounds.

Methods commonly used for collection of surface soil samples are described below. Considerations
when using IS methods are provided in Attachment I-B-l-1.

5.4.1	Hand Trowel

A stainless-steel or disposable hand trowel may be used for sampling surface soil in instances where
samples are not to be analyzed for volatile organics. The hand trowel is initially used to remove the
uppermost 2 inches of soil and is then used to acquire a representative sample of deeper materials to
a depth of 6 inches. Generally, only samples within the upper 6 inches of soil should be sampled
using these methods. The depth of the sample shall be recorded in the surface and shallow soil
sample log (Figure I-B-l-3). The soil classification shall include all the information outlined in
Procedure I-E, Soil and Rock Classification.

Soil samples collected using a hand trowel are usually placed into pre-cleaned, wide-mouth glass
jars. The jar is then sealed with a tight-fitting cap, labeled according to Procedure III-E, Record
Keeping, Sample Labeling, and Chain-of-Custody, and placed on ice in a cooler in accordance with
Procedure III-F, Sample Handling, Storage, and Shipping. All sampling equipment must be
decontaminated prior to each use according to the methods presented in Procedure I-F, Equipment
Decontamination.

5.4.2	Hand Auger

A soil recovery hand auger consisting of a metal rod, handle, detachable stainless-steel core barrel,
and inner sleeves can be used to obtain both surface soil and trench samples. Multiple extensions can
be connected to the sampler to facilitate the collection of samples at depths up to 15 feet below the
existing ground surface.

Pre-cleaned sample liners are loaded into the core barrel prior to sampling. In general, these liners
are used not only to collect samples, but also to serve as the sample container. Alternatively, in
instances where VOCs are not to be analyzed or where not enough samples can be collected to
completely fill a liner, samples can be transferred to wide-mouth glass jars. In either case, the sample
shall be labeled according to Procedure III-E, Record Keeping, Sample Labeling, and
Chain-of-Custody and immediately placed on ice in a cooler as indicated in Procedure III-F, Sample
Handling, Storage, and Shipping. To minimize possible cross-contamination, the soil recovery hand
auger and sample liners shall be decontaminated prior to each use according to the procedures
described in Procedure I-F, Equipment Decontamination.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
15 of 34

5.4.3 Slide Hammer Sampling

In instances where the soil type precludes the collection of soil samples using the soil recovery hand
auger, a manually operated slide hammer can be used to collect relatively undisturbed soil samples
from excavations and surface soils. The slide hammer consists of a 6- to 12-inch core barrel that is
connected to the slide hammer portion of the device using detachable extensions.

The core sampler is typically loaded with two to four sample liners, depending on the liner length,
which are not only used to acquire the samples, but also serve as the sample container. Immediately
following acquisition, samples shall be labeled according to Procedure III-E, Record Keeping,
Sample Labeling, and Chain-of-Custody and immediately placed on ice in a cooler as indicated in
Procedure III-F, Sample Handling, Storage, and Shipping.

All of the sampling equipment that comes into contact with the sample medium shall be
decontaminated in accordance with Procedure I-F, Equipment Decontamination. Split-barrel slide
hammer core samplers, which have recently become available, are much easier to decontaminate
than the older, single-piece core barrel, and should be used in place of the older core barrels where
possible.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
17 of 34

FIELD LOG OF TRENCH/PIT

Project Name

Trench Number

Project Number

Elevation and Datum

Location

Equipment Supplier

Operator

Date and Time Started

Date and Time Completed

Equipment Type

Trench Orientation

Total Depth

Total Number of Samples

Bucket Width

Trench Length

Trench Width

No. Of
Samples

Bulk

Ss

Drive

Hand Auger

Geologist or Hydrogeologist/Date

Check by/Date

SOIL DESCRIPTION

LITHOLOGY

DEPTH

(FEET)

DESCRIPTION

uses

SYMBOL

Est. % of

COMMENTS

G

S

F















Description taken feet













from end of trench.































































































































































































































Figure l-B-1 -2: Field Log of Trench/Pit

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
19 of 34

SURFACE AND SHALLOW SOIL SAMPLE LOG

Project Number Project Name

Date

Time

Sample Identification Number and Time

Checked by

Sampled by

Recorded by

Method of Collection

Surface Description

Notes

Soil Sample Data

Location

Coordinates

Elevation

LITHOLOGY

DEPTH

(FEET)

DESCRIPTION

uses

SYMBOL

Est. % of

COMMENTS

G

S

F



































































































































































































































Figure l-B-1 -3: Surface and Shallow Soil Sample Log

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
21 of 34

5.4.4 Hand Sampling Using Sample Liners

Surface soil samples can sometimes be collected by hand using just the sample liners. This method
can be used in cases where the surface soils are soft or where it is advantageous to minimize the
disturbance of the sample (such as when sampling for volatiles). Obtaining surface soil samples with
this method consists merely of pushing or driving the sample tube into the ground by hand.

The sample liner (with the collected sample inside) is then removed from the ground and capped
with Teflon film and plastic end caps. The sample is labeled according to Procedure III-E, Record
Keeping, Sampling Labeling, and Chain-Of-Custody and immediately placed on ice in a cooler. All
liners shall be decontaminated prior to use in accordance with Procedure I-F, Equipment
Decontamination. Since the only pieces of equipment used are the sample liners, this method helps
to minimize the required amount of equipment decontamination.

5.5 Volatile Organics Screening and Headspace Analysis

Volatile organics screening and headspace analysis is performed to preliminarily assess if the sample
contains VOCs. Volatile organics screening and headspace analysis of samples shall be performed
using a portable organic vapor analyzer (OVA), a portable photoionization detector (PID), or other
similar instrument.

Volatile organics screening and headspace analysis is intended as a field screen for the presence of
VOCs. The method measures the presence or absence of VOCs in the headspace (air) above a soil
sample. Various factors affect the level of VOCs volatilizing from soils, such as concentration in the
soil, temperature of the soil and air, organic carbon content of the soil, equilibration time, moisture
content of the soil, and the chemical and physical characteristics of the VOCs. Therefore, headspace
readings can only be regarded as qualitative assessments of volatiles, and caution should be
exercised if using this technique to select samples for analytical testing. OVA and PID readings can
vary because the two instruments have different sensitivities to the various VOCs and are usually
calibrated relative to different gas standards (i.e., methane for the OVA and isobutylene for the PID).

In order to screen samples for VOCs, the instrument probe shall be inserted into the top of the
sample liner immediately after the sampler is opened. The instrument response (normally in parts per
million) is then recorded in the field notebook and/or the field log.

For headspace analysis, a portion of the sample is transferred into a zipper storage bag or pre-cleaned
glass jar, which is then sealed and agitated. The VOCs are allowed to volatilize into the headspace
and equilibrate for 15 to 30 minutes. Next, the instrument probe is then inserted into the container to
sample the headspace, and the instrument response is recorded in the field notebook and/or the field
log.

6. Records

Soil classification information collected during soil sampling should be documented in borehole,
trench, and surface soil log forms. All log entries shall be made in indelible ink. Information

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
22 of 34

concerning sampling activities shall be recorded on sample log forms or in the field logbook. The
CTO Manager or designee shall review all field logs on at least a monthly basis. Procedures for these
activities are contained in this manual. Copies of this information should be sent to the CTO
Manager and to the project files.

7.	Health and Safety

Field Personnel shall perform work in accordance with the current (or as contractually obligated)
United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2008) and site-specific health and safety plan.

8.	References

ASTM International (ASTM). 2005. Standard Guide for Direct Push Soil Sampling for
Environmental Site Characterizations. ASTM D6282-98. West Conshohocken, PA.

	. 2006. Standard Practice for Rock Core Drilling and Sampling of Rock for Site

Investigation. D2113-06. West Conshohocken, PA.

Department of Defense, United States (DoD). 2005a. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

	. 2005b. Uniform Federal Policy for Quality Assurance Project Plans, Part 2B: Quality

Assurance/quality Control Compendium: Minimum QA/QC Activities. Final Version 1. DoD:
DTIC ADA 426957, EPA-505-B-04-900B. In conjunction with the U. S. Environmental
Protection Agency and the Department of Energy. Washington: Intergovernmental Data Quality
Task	Force.	March.	On-line	updates	available	at:

http://www2.epa.gov/sites/production/files/documents/qaqc_vl_0305.pdf.

	. 2012. Uniform Federal Policy for Quality Assurance Project Plans, Part 2A: Optimized

UFP-QAPP Worksheets. Revision 1. March.

Department of the Navy (DON). 2007. Environmental and Natural Resources Program Manual.
OPNAV Instruction 5090.1C. 30 October.

	. 2010. Ammunition and Explosives Safety Ashore. NAVSEA OP 5 Volume 1, 7th Revision,

Change 11. 0640-LP-108-5790. Commander, Naval Sea Systems Command. July 1.United States
Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health Requirements
Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-A-6, Investigation-Derived Waste Management.

Procedure I-C-l, Monitoring Well Installation and Abandonment.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
23 of 34

Procedure I-E, Soil and Rock Classification.

Procedure I-F, Equipment Decontamination.

Procedure I-I, Land Surveying.

Procedure III-E, Record Keeping, Sample Labeling, and Chain-of-Custody.

Procedure III-F, Sample Handling, Storage, and Shipping.

9. Attachment

Attachment I-B-l-1: Sampling and Handling Procedure: Analysis of Soil for Volatile Organic
Compounds

-------
This page intentionally left blank

-------
Attachment l-B-1-1
Sampling and Handling Procedure:
Analysis of Soil for Volatile Organic Compounds

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
27 of 34

1. Laboratory Requirements

The laboratory must be capable of performing (1) United States (U.S.) Environmental Protection
Agency (EPA) Solid Waste (SW)-846 Method 5035 and (2) Method 8260, 8021, or 8015 (purgeable
hydrocarbons), depending on the project objectives (EPA 2007). The laboratory must have method
performance data to verify this capability.

Sampling and handling procedures for the analysis of soil for volatile organic compounds (VOCs)
will depend on the project objectives and the sampling approach. The laboratory is responsible for
providing the necessary sample containers with preservatives (if applicable) that meet consumable
certification requirements. The following section describes the consumable options for VOC soil
sampling. In addition, sample containers must have a sample label and be weighed prior to shipment
to the field for use. The laboratory is responsible for recording the weight of each container before
and after sampling. Alternately, EnCore-type samplers may be employed.

The laboratory must provide a minimum of three prepared containers, or EnCore-type samplers, for
each soil sample analyzed for VOCs.

Disposable coring devices (hereafter referred to as coring devices): either vendor-calibrated
sample coring devices, or EnCore-type samplers. One coring device sampler per sampling
location, plus additional coring devices (5 percent) in case of breakage.

The number and type of laboratory prepared sample containers will depend upon the
sampling scheme employed.

For discrete soil VOCs, two 40 milliliter (mL) volatile organic analyte (VOA) vials with
5 mL of ASTM International (ASTM) Type II water, single-use magnetic stir bar with
Teflon lined septa cap, one VOA vial with 5 mLs of methanol with a Teflon lined septa cap,
and sample label, or three EnCore-type samplers.

For incremental soil VOC samples, the total number of sample containers will depend upon
the number of increments collected. The laboratory shall provide containers which contain a
maximum of 30 mL of methanol (or as dictated by Federal Laws for transporting Exempted
Limited Quantities of Dangerous Goods (49 CFR 100-185) with a Teflon lined septa cap,
and sample label.

Reagent/trip blanks: laboratory-prepared in identical fashion to sample vials.

Temperature blanks: laboratory-prepared.

2-ounce glass jars with Teflon-lined lid: for dilution purposes and percent moisture
determination.

2. Supplies

Nitrile or equivalent gloves.

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
28 of 34

3. Field Sampling

The following directions apply to all sampling techniques for soil coring devices: For reasons stated
in section 3.4ofthis attachment and explained in detail in Sections 8.2.1.8 and A7.2 of EPA Method
5035, core-type (i.e., Terra Core, EnCore, etc.) samplers are recommended for sample collection, not
sample collection and transport (EPA 2007).

Always wear clean gloves while handling sample containers to help prevent soil and other
debris from adding to the weight of the vial. Always don a new pair of gloves and use a new
core sampler for each sampling location.

Whenever possible, collect the soil samples for VOC analysis in place. If this is not possible,
practical, or safe, collect the sample from a sample liner, or if absolutely necessary, from a
backhoe bucket. Avoid having particles of soil adhering to the grooves of the screw cap or
the container threads.

Collect VOA samples as quickly as possible to avoid unnecessary VOC losses. EPA Region

9	recommends total exposure of the soil sample to ambient conditions should not exceed

10	seconds.

Once the soil has been transferred to the sample container, screw the cap back on and mark
the sample ID on the label with a ballpoint pen. Do not use a pen that has high solvent
concentrations in the ink such as a Sharpie.

Place the VOA vial inside a cooler containing either wet ice in sealed bags or gel ice.

Collect the number of sample containers as describe in Section 2 of this standard operating
procedure at each sampling location. The same core sampler may be used to prepare all
containers. Duplicate samples require collecting additional sample containers. For percent
moisture purposes, soil must also be collected in 2-ounce or greater glass jars with
Teflon-lined lids at each sampling location. If other analyses are being conducted for the
sampling location, then the percent moisture may be obtained from other sample containers.
The 2-ounce jar will be completely filled with zero headspace. If other analyses are not
being conducted at the sampling location, then an additional sample must be collected in
another 2-ounce glass jar for percent moisture.

When incrementally collecting samples from a liner for non-VOC analysis, a core sampler
may be used to obtain equal incremental sample volumes. The liner will have been sliced
open prior to incremental sample collection for access to the entire length of the sample.

Depending on the 1) pre-selected volume to be collected per sample, 2) the sample/liner
length available for incremental sampling, and 3) the size of the core tool, collect as many
cores from the entire soil sample/liner section that will total to the required sample volume.
For example, if 30 grams is the volume to be collected per sample location, the sample/liner
length is 6 inches, and a 5 gram core tool is used, then 6 incremental samples, located
throughout the sample length to provide adequate, representative coverage of the entire

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
29 of 34

6 inches of sample, would be collected (i.e., 6 incremental samples could be taken at equally
spaced locations across the sample length, totaling 30 grams of sample).

Collect one equipment blank per laboratory or vendor shipment of Terra Core, as described
in Procedure III-B, Field QC Samples (Water, Soil), unless the syringes are certified clean
(e.g., certificate of analysis or equivalent documentation) by the vendor.

Place samples in bubble wrap or other protective covering. Place custody seals on the
covering. Custody seals or tape must not be placed directly on the sample vials, as this will
interfere with the analytical instrumentation, final weight of the sample, and ultimate sample
VOC concentration.

The following additional directions for VOC soil sample collection are taken from EPA SW-846
Method 5035A Appendix A7.0 (EPA 2002).

Collection of Samples for Analysis

After a fresh surface of the solid material is exposed to the atmosphere, the subsample
collection process should be completed in the least amount of time to minimize the loss of
VOCs due to volatilization. Removing a subsample from a material should be done with the
least amount of disruption (disaggregation) as possible. Additionally, rough trimming of the
sampling location's surface layers should be considered if the material may have already lost
VOCs (been exposed for more than a couple of minutes) or if it might be contaminated by
other waste, different soil strata, or vegetation. Removal of surface layers can be
accomplished by scraping the surface using a clean spatula, scoop, knife, or shovel
(ASTM 2005, Hewitt et al. 1999).

Subsampling of Cohesive Granular but Uncemented Materials Using Devices Designed to
Obtain a Sample Appropriate Analysis

Collect subsamples of the appropriate size for analysis using a metal or rigid plastic coring
tool. For example, coring tools for the purpose of transferring a subsample can be made from
disposable plastic syringes by cutting off the tapered front end and removing the rubber cap
from the plunger or can be purchased as either plastic or stainless-steel coring devices. These
smaller coring devices help to maintain the sample structure during collection and transfer to
the VOA vials, as do their larger counterparts used to retrieve subsurface materials. When
inserting a clean coring tool into a fresh surface for sample collection, air should not be
trapped behind the sample. If air is trapped, it could either pass through the sampled material
causing VOCs to be lost or push the sample prematurely from the coring tool.

The commercially available EasyDraw Syringe, Powerstop Handle, and Terra Core sampler
coring devices are designed to prevent headspace air above the sample contents. For greater
ease in pushing into the solid matrix, sharpen the front edge of these tools. The optimum
diameter of the coring tool depends on the following:

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
30 of 34

Size of the opening on the collection vial or bottle (tool should fit inside mouth)

Dimensions of the original sample, particle size of the solid materials (e.g., gravel-
size particles would require larger samplers)

Volume of sample required for analysis

For example, when a 5-gram (g) subsample of soil is specified, only a single 3-cubic-
centimeter (cm3) volume of soil has to be collected (assuming the soil has density of
1.7 g/cm3). Larger subsample masses or more subsample increments are preferred as the
heterogeneity of the material increases. After an undisturbed sample has been obtained by
pushing the barrel of the coring tool into a freshly exposed surface and then removing the
filled corer, quickly wipe the exterior of the barrel with a clean disposable towel.

The next step varies depending on whether the coring device is used for sample storage and
transfer or solely for transfer. If the coring tool is used as a storage container, cap the open
end after ensuring that the sealing surfaces are cleaned. If the device is to be solely used for
collection and not for storage, immediately extrude the sample into a VOA vial or bottle by
gently pushing the plunger while tilting the VOA vial at an angle (to avoid splashing any
deionized water or methanol). The volume of material collected should not cause excessive
stress on the coring tool during intrusion into the material, or be so large that the sample
easily falls apart during extrusion. Obtain and transfer samples rapidly (<10 seconds) to
reduce volatilization losses. If the vial or bottle contains ASTM reagent Type II water, hold
it at an angle when extruding the sample into the container to minimize splashing. Just
before capping, visually inspect the lip and threads of the sample vessel, and remove any
foreign debris with a clean towel, allowing an airtight seal to form.

Devices that Can Be Used for Subsampling a Cemented Material

The material requiring sampling may be so hard that even metal coring tools cannot
penetrate it. Subsamples of such materials can be collected by fragmenting a larger portion
of the material using a clean chisel to generate aggregate(s) of a size that can be placed into a
VOA vial or bottle. When transferring the aggregate(s), precautions must be taken to prevent
compromising the sealing surfaces and threads of the container. Losses of VOCs by using
this procedure are dependent on the location of the contaminant relative to the surface of the
material being sampled. Therefore, take caution in the interpretation of the data obtained
from materials that fit this description. As a last resort, when this task cannot be performed
on site, a large sample can be collected in a vapor-tight container and transported to the
laboratory for subsampling. Collect, fragment, and add the sample to a container as quickly
as possible.

Devices that Can Be Used for Subsampling a Non-cohesive Granular Material

As a last resort, gravel, or a mixture of gravel and fines that cannot be easily obtained or
transferred using coring tools, can be quickly sampled using a stainless-steel spatula or

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
31 of 34

scoop. If the collection vial or bottle contains ASTM reagent Type II water, transfer samples
with minimal splashing and without the spatula or scoop contacting the liquid contents. For
some solids, a wide-bottom funnel or similar channeling device may be necessary to
facilitate transfer to the container and prevent compromising the sealing surfaces of the
container. Take caution when interpreting the data obtained from materials that fit this
description. Loss of VOCs is likely due to the nature of the sampling method and the non-
cohesive nature of the material, which exposes more surface area to the atmosphere than
other types of samples. During the sampling process, non-cohesive materials also allow
coarser materials to separate from fines, which can skew the concentration data if the
different particle sizes, which have different surface areas, are not properly represented in
the sample.

Use of the EnCore Sampler (or Equivalent) for Sample Transport and Storage

The EnCore sampler is a sampling device that can be used as both a simultaneous coring tool
for cohesive soils and a transport device to a support laboratory (field or off site). The
EnCore sampler is intended to be a combined sampler-storage device for soils until a
receiving laboratory can initiate either immediate VOC analysis, or preserve extruded soil
aliquots for later VOC analysis. It is meant to be disposed of after use. The commercially
available device is constructed of an inert composite polymer. It uses a coring/storage
chamber to collect either a 5-gram or 25-gram sample of cohesive soils. It has a press-on cap
with hermetically a vapor-tight seal and locking arm mechanism. It also has a vapor-tight
plunger for the non-disruptive extrusion of the sample into an appropriate container for VOC
analysis of soil.

An individual disposable EnCore sampler (or equivalent) is needed for each soil aliquot
collected for vapor partitioning or ASTM reagent Type II water sample preparation. Upon
soil sample collection, store the EnCore sampler is at 4 ±2 degrees centigrade (°C) until
laboratory receipt within 48 hours. Upon laboratory receipt, soil aliquots are extruded to
appropriate tared and prepared VOA vials.

Validation data have been provided to support use of the EnCore sampler for VOC
concentrations in soil between 5 and 10 parts per million, for two sandy soils, with a 2-day
holding time at 4 ±2°C. Preliminary data (Soroni et al. 2001) demonstrate an effective 2-day
(48-hour) holding time at 4 ±2°C for three sandy soil types with VOC concentrations at
100 parts per billion (ppb) (benzene and toluene at 300 ppb), as well as an effective 1- or
2-week holding time at <-7°C (freezing temperature). Recent published work (EPA 2001)
neither definitively supports nor shows the EnCore device to be ineffective for sample
storage at these preservation temperatures. Soils stored in the EnCore device for 2 calendar
days at 4 ± 2°C are subject to loss of benzene, toluene, ethylbenzene, and xylene (BTEX)
compounds by biodegradation if the soil is an aerated, biologically active soil (e.g., garden
soil) (Soroni et al. 1999), but this BTEX loss is eliminated for up to 48 hours under freezing
conditions (Hewitt 1999).

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
32 of 34

Further details on the EnCore sampler can be found in ASTM D4547-09 (ASTM 2009) or other
publications.

Since Naval Facilities Engineering Command, Pacific action levels for VOCs in soil are typically
associated with EPA Region 9 preliminary remediation goals for residential exposure scenarios, it is
recommended that if EnCore samplers are used, they be frozen on site prior to shipment to the
laboratory or extruded into a 40-mL VOA vial before shipment.

4.	Sample Shipping and Holding Times

Samples preserved with water may be shipped either at 4 ±2°C or frozen at -7°C. The primary
difference between the two shipping temperatures is the allowable holding time of the sample
between sample collection and sample analysis. Samples shipped at 4 ±2°C must either be received
and analyzed by the laboratory within 48 hours of sample collection or be received by the laboratory
within 48 hours, frozen upon receipt, and analyzed within 14 days of sample collection. Samples
shipped at -7°C and received/maintained by the laboratory in a frozen state must be analyzed within
14 days of sample collection.

If soil samples are to be field frozen, place the frozen samples in a cooler containing fresh, frozen gel
packs or an ice and rock salt mixture, and ship the cooler using an overnight carrier. Dry ice may be
used as a refrigerant for sample shipment, but must be coordinated with the overnight carrier in
advance. The sample vials and caps must never be placed in direct contact with the dry ice since
cracking may occur.

Soil or sediment samples contained in methanol and 2-ounce glass jars may be shipped in standard
coolers using conventional shipping protocols described in Procedure III-F, Sample Handling,
Storage, and Shipping, if the sample appears to have a moisture content that might cause the sample
to expand and the glass jar to break due to freezing. If soil samples contained in 2-ounce glass jars
are shipped in this manner, then trip blanks must accompany them during shipment.

Reagent/trip blanks that contain the same volume of ASTM Type II water and sample label used in
the sample VOA vials must be included in each shipment. The reagent/trip blanks will be packaged,
shipped, and analyzed in the same manner as field samples. Reagent/trip blanks will be analyzed to
evaluate cross-contamination during shipment and to identify potential reagent contamination issues.

5.	Laboratory Receipt

Upon receipt by the analytical laboratory, the sample temperature must be measured and recorded.
The laboratory should note whether the samples are frozen. The samples must be logged in and
assigned an analysis date to ensure that samples are analyzed within the 14-day holding time.

Once the samples have been logged in, they are placed in a freezer at 0°C or colder until they are
analyzed. Samples arriving in a non-frozen state (greater than 0°C) are to be frozen upon receipt or

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:
Revision Date:
Page:

l-B-1
May 2015
33 of 34

analyzed within 48 hours of sample collection. If the duration of sample shipment exceeds 48 hours,
the non-frozen samples should be analyzed on the day of laboratory receipt.

The laboratory will prepare the samples for analysis as dictated by laboratory standard operating
procedures and SW-846 Method 5035, and analyzed by Method 8260, 8021, or 8015 (purgeable
hydrocarbons), depending on the project objectives.

6. References

49 Code of Federal Regulations (CFR) 100-185. Hazardous Materials and Oil Transportation.

ASTM International (ASTM). 2005. Standard Guide for Direct Push Soil Sampling for
Environmental Site Characterizations. ASTM D6282-98. West Conshohocken, PA.

	. 2009. Standard Guide for Sampling Waste and Soils for Volatile Organic Compounds.

D4547-09. West Conshohocken, PA.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

Environmental Protection Agency, United States (EPA). 2002. Method 5035A Closed System Purge
and Trap and Extraction for Volatile Organics in Soil and Waste Samples, Draft Revision 1.
Office of Solid Waste. July.

	. 2007. Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, SW-846. 3rd

ed., Revision 6. Office of Solid Waste. November. On-line updates at:
http://www.epa.gov/epawaste/hazard/testmethods/sw846/online/index.htm.

Hewitt, Alan. D. 1999. Frozen Storage of Soil Samples for VOC Analysis. Environmental Testing &
Analysis, 8 (5), pp. 18-25, 46.

Hewitt, Alan. D. and K. F. Myers. 1999. Sampling and On-Site Analytical Methods for Volatiles in
Soil and Groundwater—Field Guidance Manual, Special Report 99-16. Hanover, NH: U.S. Army
Cold Regions Research and Engineering Laboratory. November.

Soroni, S. S. and J. F. Schaborn. 1999. Performance of the Disposable EnCore Sampler for Storing
Soil for Volatile Organic Analysis. Proceedings of the 15th Annual Waste Testing and QA
Symposium, EPA. Washington, pp. 129-134.

Soroni, S. S., J. F. Schaborn and J. F. Rovani. 2001. Validation of a New Soil VOC Sampler:
Performance of the En Core Sampler for Storage of Low VOC Concentrations and EPA Method
1311 Volatile Organic Analytes. Topical Report WRI-01-R005; Laramie, WY: Western Research
Institute.

Procedure III-B, Field QC Samples (Water, Soil).

-------
NAVFAC Pacific ER Program
Soil Sampling

Procedure Number:	l-B-1

Revision Date:	May 2015

Page:	34 of 34

Procedure III-F, Sample Handling, Storage, and Shipping.

-------
NAVFAC Pacific ER Program

Procedure Number:

i-B-2

Geophysical Testing

Revision Date:

May 2015



Page:

1 of 17

Geophysical Testing

1.	Purpose

This section sets forth the standard operating procedure for acquiring surface geophysical data to
facilitate the collection of geologic, hydrogeologic, and geotechnical data related to hazardous waste
site characterization. This procedure is for use by personnel working on the United States Navy
Environmental Restoration (ER) Program, Naval Facilities Engineering Command (NAVFAC),
Pacific.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the Uniform Federal Policy-Quality Assurance Project Plan
(DoD 2005). As professional guidance for specific activities, this procedure is not intended to
obviate the need for professional judgment during unforeseen circumstances. Deviations from this
procedure while planning or executing planned activities must be approved and documented by the
following prime contractor representatives: the CTO Manager and the Quality Assurance (QA)
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

This procedure has been developed to help personnel: (1) determine whether surface geophysics
should be used at a site; (2) choose the most applicable methods for a particular objective; and (3)
implement proper field procedures. The specific supporting information explaining how various
geophysical techniques will be applied shall be defined in the project-specific work plan (WP).

3.	Definitions

For a more complete set of terms and definitions, referto R. E. Sheriff (1991).

3.1 Coupling

Coupling is the interaction between systems, and includes the following:

A device for fastening together, as the plugs for connecting electrical cables.

Aspects, which affect energy transfer. Thus the "coupling of a geophone to the ground"
involves the quality of the plant (how firmly the two are in contact) and also considerations
of the geophone's weight and base area because the geophone-ground coupling system has
natural resonances and introduces a filtering action.

The type of mutual electrical relationship between two closely related circuits. As coupling
would exclude dc voltages by employing a series capacitive element. Direct coupling may
exclude higher frequency signals by using a capacitive element across the inputs or may
allow all components to pass.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
2 of 17

Capacitive coupling may occur because of mutual capacitive impedance, as between the
wires in induced polarization (IP) circuits (see Section 3.6) or between a wire and ground.

Inductive coupling occurs because of mutual inductive impedance, such as between
grounded IP transmitter and receiver circuits, especially at higher frequencies, greater
distances, or lower earth resistivity. This may give rise to false IP anomalies. Also called
electromagnetic (EM) coupling.

Resistive coupling in IP surveying is due to leakage between wires, between a wire and
ground, or through the resistance of the ground itself between two grounded circuits.

3.2	Electrical Log

A generic term that encompasses all electrical borehole logs (spontaneous potential [SP],
normal, lateral, laterologs, induction, microresistivity logs).

Also used for records of surface resistivity surveying; to compare electrical survey.

Electrolog, a borehole log, which usually consists of SP and two or more resistivity logs,
such as short and long normal and long lateral resistivity logs. Electrolog is a Dresser Atlas
trade name.

3.3	Electrical Sounding

Electrical sounding is an IP, resistivity method, or electromagnetic method in which electrode or
antenna spacing is increased to obtain information from successively greater depths at a given
surface location. Electromagnetic sounding can also be done with a fixed spacing by varying the
frequency (time-domain technique). Electrical sounding is intended to detect changes in resistivity of
the earth with depth at this location (assuming horizontal layering).

Electrical Survey:

Measurements at or near the earth's surface of natural or induced electrical fields to map
mineral concentrations or for geological or basement mapping. (See electrical profiling,
electrical sounding, electromagnetic method, resistivity method, self-potential method,
induced-polarization method, telluric method, and magnetotelluric method).

Electrical logs run in a borehole.

3.4	Electromagnetic Methods

A method in which the magnetic or electrical fields associated with artificially generated subsurface
currents are measured. In general, EM methods are those in which the electric and magnetic fields in
the earth satisfy the diffusion equation (which ignores displacement currents) but not Laplace's
equation (which ignores induction effects) nor the wave equation (which includes displacement
currents). One normally excludes methods that use microwave or higher frequencies (and that
consequently have little effective penetration) and methods that use direct coupling or very low
frequencies in which induction effects are not important (resistivity and IP methods). Some methods
that employ natural energy as the source, such as Afinag, are usually classified as EM methods,
whereas other methods using natural energy, such as the magnetotelluric method, are not.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
3 of 17

3.5	Geophysics

The study of the earth by quantitative physical methods, especially by seismic reflection and
refraction, gravity, magnetic, electrical, and radiation methods.

The application of physical principles to study the earth. Includes the branches of:
(a) seismology (earthquakes and elastic waves); (b) geothermometry (heating of the earth,
heat flow, and volcanology and hot springs); (c) hydrology (ground and surface water and
sometimes including glaciology); (d) oceanography; (e) meteorology; (f) gravity and
geodesy (the earth's gravitational field and the size and form of the earth); (g) atmospheric
electricity and terrestrial magnetism (including ionosphere, Van Allen belts, telluric
currents); (h) tectonophysics (geological processes in the earth); and (i) exploration and
engineering geophysics. Geochronology (the dating of earth history) and geocosmogony (the
origin of the earth). These are sometimes added to the foregoing list. Enthusiasts in
particular branches are inclined to appropriate the word "geophysics" to their own branch
exclusively, whether that branch be ionospheric studies or exploration for oil.

Exploration geophysics is the use of seismic, gravity, magnetic, electrical, EM, etc., methods
in the search for oil, gas, minerals, water, etc., for economic exploitation.

3.6	Induced Polarization

IP is an exploration method involving measurement of the slow decay of voltage in the
ground following the cessation of an excitation current pulse (time-domain method) or low
frequency (below 100 Hertz) variations of earth impedance (frequency-domain method).
Also known as the overvoltage method. Refers particularly to electrode polarization
(overvoltage) and membrane polarization of the earth. Also called induced potential,
overvoltage, or interfacial polarization. Various electrode configurations are used.

The production of a double layer of charge at mineral interfaces or of changes in such double
layers as a result of applied electric or magnetic fluids.

3.7	Low-velocity Layer

Weathering; a near-surface belt of very low-velocity material.

A layer of velocity lower than that of shallower refractors (i.e., blind zones).

The B-layer in the upper mantle from 60 to 250 kilometers deep, where velocities are about
6 percent lower than in the outermost mantle.

The region just inside the earth's core.

3.8	Resistance

Resistance is the opposition to the flow of a direct current.

3.9	Resistivity

Resistivity is the property of a material that resists the flow of electrical current. Also called specific
resistance. The ratio of electric-field intensity to current density. The reciprocal of resistivity is
conductivity. In nonisotropic material, the resistivity is a tensor.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
4 of 17

3.10	Resistivity Logs

Well logs that depend on electrical resistivity, normal, lateral, laterolog, and induction log.
Most resistivity logs derive their readings from 10 to 100 cubic feet of material about the
sonde. Microresistivity logs, however, derive their readings from a few cubic inches of
material near the borehole wall.

Records of surface resistivity methods.

3.11	Resistivity M ethod

Observation of electric fields caused by current introduced into the ground as a means for
studying earth resistivity in geophysical exploration. The term is normally restricted to those
methods in which a very low frequency or direct current is used to measure the apparent
resistivity. Includes electrical profiling and electrical sounding. Various array types are used.

Sometimes includes IP and EM survey methods also.

3.12	Seismic Survey

Seismic survey is a program for mapping geologic structure by creating seismic waves and observing
the arrival time of the waves reflected from acoustic-impedance contrasts or refracted through
high-velocity members. A reflection survey is usually implied unless refraction survey is specifically
mentioned. The energy source for creating the waves is usually impulsive (i.e., energy is delivered to
the earth for a very short period of time) although energy is introduced for considerable time with the
Vibroseis method. The energy is detected by arrays of geophones or hydrophones connected to
amplifiers, and the information is amplified and recorded for interpretation. The data often are
processed to enhance the wanted information (signal) and displayed in record-section form. Signal is
recognized as a coherent event, although noise often is coherent also. Events considered to be
reflections from acoustic-impedance contrasts (reflectors) are used to locate the reflectors, it being
assumed that their attitudes are that of the geologic structure. Events attributed to be head waves are
used to locate the refractors of which they are characteristic, it being assumed that the attitudes of
these refractors are those of the geologic structure. Velocity analysis is also done on reflection data
where the offset varies.

3.13	Self-potential/Spontaneous Potential

The direct coupling or slowly varying natural ground voltage observed between nearby
non-polarizing electrodes in field surveying. In many mineralized areas, this is caused by
electrochemical reaction at an electrically conducting sulfide body.

A well log of the difference between the potential of a movable electrode in the borehole and
a fixed reference electrode at the surface. The SP results from electrochemical SP and
electrokinetic potentials, which are present at the interface between permeable beds adjacent
to shale. In impermeable shales, the SP is fairly constant at the shale base-line value. In
permeable formations, the deflection depends on the contrast between the ion content of the
formation water and the drilling fluid, the clay content, the bed thickness, invasion, and bed-
boundary effects, etc. In thick, permeable, clean non-shale formations, the SP has the fairly
constant sand line value, which will change if the salinity of the formation water changes. In
sands containing disseminated clay (shale), the SP will not reach the sand line and a
pseudostatic SP value will be recorded. The SP is positive with respect to the shale base line
in sands filled with fluids fresher than the borehole fluid.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
5 of 17

3.14	Telluric

Telluric means of the earth, and often refers specifically to telluric currents.

3.15	Telluric Current

Telluric current is a natural electrical earth current of very low frequency that extends over large
regions and may vary cyclically in that direction. Telluric currents are widespread, originating in
variations of the earth's magnetic field.

4.	Responsibilities

CTO Managers are responsible for determining whether surface geophysical methods should be used
on a project and if so, which methods should be used. This information should be included in the
project-specific WP. The objectives of the geophysical investigation shall be stated explicitly in the
subcontract WP. Further, deliverables by the subcontractor shall be clearly identified in the WP so
the prime contractor knows what to expect from the subcontractor. The CTO Manager is responsible
for ensuring that all personnel involved in sampling and/or testing shall have the appropriate
education, experience, and training to perform their assigned tasks as specified in Chief of Naval
Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The Field Manager (FM) is responsible for ensuring that the appropriate selected procedures are
conducted according to the instructions in this manual and the project specific sampling plan. In
many cases, subcontractors will conduct these procedures. In these situations, the FM is responsible
for overseeing and directing the activities of the subcontractor. The need to establish site-specific
quality control procedures is particularly important.

Field personnel are responsible for the implementation of this procedure.

5.	Procedures

5.1 Method Summary

A wide variety of surface-based geophysical methods exist that may apply to contamination
delineation, geologic, hydrogeologic, or other site characterization/investigation requirements. In
general, geophysical exploration methods provide for a non-invasive mapping of subsurface features
through the measurement of the physical properties of a subsurface. Typically, an active signal
(e.g., acoustic or electrical) propagates into the earth and the interaction of the signal with the
subsurface materials is measured at the surface. Interpretation of the data provides a map or image of
the subsurface. For example, electrical conductivity of soil governs the propagation of an electrical
signal through the subsurface. The geologic/hydrologic/waste characteristics are then inferred from
an interpretation of the data or correlated with borehole data.

For a geophysical survey to be successful, the method of choice must be capable of resolving a
particular physical characteristic that relates to the goals of the investigation. For example, if a zone
of contaminated groundwater is being investigated by an electrical method, the electrical
conductivity of the contaminated portion of the aquifer should be sufficiently different from the
uncontaminated portion to allow for identification of the 'plume'. If the target (i.e., the

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
6 of 17

high-conductivity plume in this example) does not contrast sufficiently with the uncontaminated
portion, then the geophysical survey will not be successful. Often, preliminary calculations or atrial
survey can be performed to evaluate a particular method.

For purposes of this procedure, the geophysical methods discussed herein are classified as follows:

Seismic Methods: These include seismic refraction and reflection methods and are typically
applied to investigate depths to water or geologic structures (stratigraphic horizons or depth

Electrical Methods: A wide variety of these exist including Direct Current (DC) Resistivity,
Low-Frequency EM Induction (i.e., loop-loop methods), Very Low Frequency EM, Ground
Penetrating Radar (GPR), Complex Resistivity/IP, metal detection equipment, and SP
profiling. These respond to variations in the electrical properties of a site, specifically the
electrical conductivity and (for GPR) the dielectric/permittivity constant. Applications
include general geologic/hydrologic mapping, identification of solute 'plumes,' and the
detection of conductive metallic debris/objects.

Potential Field Methods: Some methods do not require an active signal source and instead
measure naturally occurring potential fields of the earth. These include measurements of the
earth's magnetic or gravitational fields. Magnetic methods are often used to detect the
response of the earth's magnetic field to metallic objects and can be very effective in locating
buried metallic materials. Gravity methods respond to subtle density variations and are
typically used to map the depth/thickness of alluvial basins or to detect cavities within
consolidated sediments (e.g., Karst sinkholes).

While a number of geophysical methods may be applied at hazardous waste sites, the scope of this

procedure is limited to the following commonly applied methods:

Seismic:	Refraction

Electrical:	DC Resistivity

Often, geophysical contractors specialize in a particular survey method. The following references
may be useful to provide additional information:

Dobrin, M. B. and C. H. Savit. 1988. Introduction to Geophysical Prospecting. McGraw-Hill.

Journals: Geophysics (Society of Exploration Geophysics); Geophysical Exploration European
Association of Exploration Geophysicists; occasionally - Groundwater, Groundwater Monitoring
Review (National Water Well Association).

to bedrock).

EM Induction (Loop-Loop)

Potential Field:

GPR

Metal Detection
IP

SP Profiling
Magnetics

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
7 of 17

Sheriff, R. E. 1991. Encyclopedic Dictionary of Exploration Geophysics. Society of Exploration
Geophysics.

Telford, W. M., L. P. Geldart, R. E. Sheriff, D.A. Keys. 1998. Applied Geophysics. Cambridge
University Press.

5.2 Method Limitations/Interferences and Potential Problems

Each of the geophysical methods discussed herein are typically designed and implemented on a
site-specific basis. Exercise care to ensure that a particular method is applicable and that an
identifiable target is likely to exist. A determination must be made that the exploration target can be
resolved versus the background signal/site conditions and that cultural or other 'noise' problems will
not interfere. 'Cultural Noise' is defined as near-surface or surficial features (e.g., power lines or
traffic vibrations) that can potentially mask or overwhelm the signal produced by the subsurface
target.

All of the survey methods require field instrumentation and electronics that might be impacted by
extreme climactic variations. Check the equipment regularly (daily, at a minimum) to ensure internal
calibration. Review the manufacturers' guidelines and specifications prior to field application.

5.2.1	Seismic Method Limitations and Potential Problems

5.2.1.1 Refraction Surveys

Care should be exercised in avoiding the following potential problems:

Poorly emplaced geophones (e.g., in loose soil)

Poor couplings of induced signal (e.g. strike plate) with ground

Intermittent electrical shorts in geophone cable (never drag geophone cables)

Wet geophone connections

Vibration due to wind and traffic-induced noise

Improper gain/filter settings

Insufficient signal strength

Topographic irregularities (an accurate topographic survey is often required prior to field
operations)

5.2.2	Electrical Method Limitations and Potential Problems

5.2.2.1 DC RESISTIVITY

Measurement of electrical resistivity represents a bulk average of subsurface material resistivity. In
some instances, the resistivity of the target material may not contrast sufficiently with 'background'
material to be observed with this method, especially as the target material gets thinner and/or deeper.
If highly conductive soil/rock are present at shallow depths, electrical current may not penetrate to
depths beyond this layer. An electrical current always follows the path of least resistance.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
8 of 17

Care should be exercised in avoiding the following potential problems:

Poorly coupled electrodes (insufficient grounding)

Unshielded wires causing intermittent shorts

Background electrical noise, such as natural currents (SP or telluric effects)

EM coupling with power lines, causing the introduction of induced electrical currents into
the receiver wire

Grounded fence lines and power lines interfering with the survey

Inadequate signal power (increase current levels to produce sufficient signal to noise ratios)

Very low resistivity layer at the surface preventing the electrical field from penetrating
deeper layers

Very high resistivity layer at the surface (e.g. dry sandy gravel) preventing the electrical
field from penetrating the surface layer

5.2.2.2	EM Method

A variety of EM methods may be applied; however, in practice, the Geonics EM31-MK2 and
EM34-3 Loop-Loop instruments are usually used in hazardous waste surveys. The EM methods are
similar to DC methods in application and are sensitive to conductive materials, except for the basic
distinction that they are not electrically grounded. Complications may arise in the EM method in
developed sites because aboveground, metallic objects or electrical fields may interfere. Power lines,
automobiles, train tracks, water tanks, and other objects may completely dominate data results and
render the method useless.

5.2.2.3	GPR Methods

GPR methods are seldom useful where highly conductive conditions or clay is present at shallow
depths. The high-frequency signal propagates as a function of both electrical conductivity and
dielectric constant (permittivity). The selection of transmission frequency is important because high
frequencies are rapidly attenuated and the signal may not penetrate. Often, a choice of frequencies is
available and it is suggested to perform site-specific field tests over known, observable targets to
determine whether GPR is appropriate for use.

Care should be exercised in avoiding the following potential problems:

Improperly adjusted/configured equipment (e.g., antenna gain, filter slopes or gain
thresholds)

Insufficient signal and/or poor transmission qualities of the materials found at a site
(e.g. clay, saline water conditions)

The influence of reflected signals outside of the immediate zone of investigation upon the
radar record (e.g., fences, power poles, buildings)

5.2.2.4	Metal Detection

Metal objects that are not survey targets, including those worn or carried by the operator, might
interfere with measurements.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
9 of 17

5.2.3 Potential Field Method Limitations and Problems

5.2.3.1 Magnetics

The signal measured by a magnetometer varies with time and is subject to variations induced by
solar storms. Care should be exercised in avoiding the following potential problems:

Metal objects that are not survey targets, such as those worn or carried by the operator and
surficial metallic objects, interfering with measurements

Lack of base station control to measure background field fluctuations

Failure to maintain a constant sensor height with respect to ground elevation

5.3	Survey Design/Pre-field Preparation

5.3.1	Survey Design

Prior to performing a field investigation, it is often possible to estimate the effectiveness of a surface
geophysical survey by using data interpretation software relevant to the survey or by other
calculation methods. A sensitivity analysis is usually performed to determine if a geophysical target
possesses sufficient contrast with background conditions to be detected using surface geophysics. In
some instances, available site data or prior geophysical investigations may be available to obtain
estimates of the geophysical characteristics of the site.

5.3.2	Field Preparation

Verify that the required geophysical equipment is pre-calibrated and operational.

Establish grid locations or set up traverses for location of sampling stations.

Survey the station locations and record them on a scaled site plan.

Test and calibrate geophysical equipment.

5.4	Field Procedures

The following procedures apply to geophysical surveys conducted at a hazardous waste site.
Procedures may vary since equipment capabilities and methodologies are rapidly evolving. In
general, survey field locations, accurately record them, and ensure that the equipment is functional
and calibrated. Typically, a control or base station location will be established to check the
equipment response over the duration of the field investigation. In addition, ensure a high signal to
noise ratio can be maintained to obtain a geophysical response representative of the target/zone of
interest.

5.4.1 Seismic Refraction Methods

Use seismic refraction techniques to determine the structure of a site based upon the travel time or
velocity of seismic waves within layers. Interpretation of the travel time variation along a traverse of
geophones can yield information regarding the thickness and depth of buried strata. Seismic methods
are often used to determine depths to specific horizons of contrasting seismic velocities, such as
bedrock, clay layers, or other lithologic contrasts, and the water table (under unconfined conditions).

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
10 of 17

Procedures

Check the seismic signal and noise conditions on the instrument to verify the proper
functioning of geophones and cables and to check the instrument settings.

When the seismic field equipment does not produce hard copies of seismic records,
immediately plot the arrival time selected from the electronic display on a time/distance
graph in the field. Produce a hard copy of the data, and keep it in the record file. Problems
with improper picks are often discovered by early inspection of these plots.

Background or offsite data may be required for correlation to site conditions. Correlation of
the seismic data with electrical method results, if obtained, or with borehole or outcrop data,
may be a useful means of assigning thickness or seismic velocities.

If possible, analyze boring logs or other data to determine if low velocity (inverse layers) or
thin beds may be present that might not be detected otherwise.

Run the seismic system at a known standard base station for periodic checks of instrument
operation.

Properly store the data in digital form for subsequent processing and data evaluation.

5.4.2 Electrical Methods

5.4.2.1 DC RESISTIVITY

The resistivity method provides a measurement of the bulk electrical resistivity of subsurface
materials. Application of the method requires that a known electrical current be induced into the
ground through a pair of surface electrodes. Measure the resulting potential field (voltage) between a
second pair of surface electrodes. Evaluate the subsurface electrical properties based on the current,
voltage, and electrode position (array configuration).

Given the length of the wire cables, their connections to the electrodes, and the coupling of the
electrodes with the ground, there are a number of potential problems for obtaining reliable data
(e.g., poor electrical contact, short and open circuits). These conditions can be minimized by careful
observation of instrument readings and trends.

Procedures

Calculate and plot apparent resistivities during field acquisition as a means of quality
control. If vertical electrical sounding is performed, the data plots (curves) should be
smooth, and discontinuous jumps in the data should not occur. Profiling data should also
show a general trend in the data from one station to the next; however, abrupt changes may
occur in both sounding and profiling data due to "noise" from near-surface inhomogeneities
or electrode contact problems.

The resistivity instrument can be calibrated using standard resistors or by using the internal
calibration circuits often contained within the equipment. Calibration is particularly
important if the data are to be compared to resistivity measurements from other instruments
or other parameters, such as specific conductance of water samples.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
11 of 17

5.4.2.2 EM Methods

EM methods provide a means of measuring the electrical conductivity of subsurface soil, rock, and
groundwater. Electrical conductivity (the inverse of electrical resistivity) is a function of the type of
soil, porosity, permeability, and the conductivity of fluids in the pore spaces. The EM method can be
used to map natural subsurface conditions and conductive contaminant plumes. Additionally, trench
boundaries, buried conductive wastes, such as steel drums, metallic utility lines, and steel
underground storage tanks, might potentially be located using EM techniques.

Following factory calibration, the instruments will normally retain their accuracy for long periods;
however, the user should establish a secondary standard area at the field site for periodic
recalibration. This will provide a reference base station to check "drift" in the instrument's
performance and to permit correlation between instruments.

While precision can be easily checked by comparing subsequent measurements with the instrument
at a standard site, accuracy is much more difficult to establish and maintain.

EM instruments are often used to obtain relative measurements. For these applications, it is not
critical to maintain absolute accuracy; however, the precision of the instrument can be important. For
example, in the initial mapping of the spatial extent of a contaminant plume, a moderate level of
precision is necessary. If the same site is to be resurveyed annually to detect small changes in plume
migration and movement, a very high level of precision is necessary.

If the objective of the survey is to obtain quantitative results from the EM data for correlation to
other measurable parameters (e.g., specific conditions), proper steps should be taken to ensure good
instrument calibration. This is particularly important when performing surveys in areas of low
conductivity, where measurement errors can be significant.

The dynamic range of EM instruments varies from 1 to 1,000 millimhos/meter (mmho/m). At the
lower conductivities, near 1 mmho/m and less, it is difficult to induce sufficient current in the ground
to produce a detectable response; hence, readings may become unreliable. At conductivity values
greater than about 100 mmho/m, the received signal is no longer linearly proportional to subsurface
conductivities, and corrections must be applied to the data, if it is to be used for quantitative
purposes.

Procedures

Maintain or verify calibration records from the equipment supplier or manufacturer.
Calibrate the EM system regularly.

Prior to conducting a survey, select a temporary site on location for daily calibration checks.
Conduct calibration checks twice daily, before and after conducting daily survey operations.
Readings shall repeat to +/-5 percent. Originals of all calibration records shall remain on site
during field activities, and copies shall be submitted to the records file. The original
calibration records shall be transferred to the project files upon completion of the fieldwork.

Note: Conduct calibration checks outside the influence of power lines, buried utilities,
buried metal objects, fences, etc. on a relatively flat surface.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
12 of 17

The field operating party shall check instrument stability when there is local or distant
thunderstorm activity. EM radiation from thunderstorms can generate noise in the EM
system. It may be necessary to postpone operations during rainstorms and resume them
when they have passed.

Exercise technical judgment such that conductivity readings recorded in the field are
reasonable with respect to existing site conditions.

Record instrument sensitivity settings in the field notebook as readings are taken. Submit the
notebook to the records file.

5.4.2.3 GPR

GPR uses high frequency radio waves to acquire subsurface information. Energy is radiated
downward into the subsurface through a small antenna, which is moved slowly across the surface of
the ground. Energy is reflected back to the receiving antenna, where variations in the return signal
are continuously recorded. This data produces a continuous cross sectional "picture" or profile of
shallow subsurface conditions. These responses are caused by radar wave reflections from interfaces
of materials having different electrical properties. Such reflections are often associated with natural
hydrogeologic conditions, such as bedding, cementation, moisture content, clay content, voids,
fractures, and intrusions, as well as manmade objects. The radar method has been used at numerous
hazardous waste sites to evaluate natural soil and rock conditions, as well as to detect buried wastes
and buried metallic objects.

The radar system measures two-way travel time from the transmitter antenna to a reflecting surface
and back to the receiver antenna. Calibration of the radar system and data requires a two-step
process:

First, accurately determine the total time window (range) set by the operator.

Second, determine the EM velocity (travel time) of the local soil-rock condition.

After completing these two steps, the radar data may then be calibrated for depths of particular
features.

Calibrate the time window (range) that has been picked for the survey by using a pulse generator in
the field. This generator is used to produce a series of time marks on the graphic display, measured
in nanoseconds. These pulses are counted to determine the total time range of the radar. A calibration
curve can be made up for each radar system.

In order to precisely relate travel time to actual depth units, determine the velocity (or two-way travel
time per unit distance) for the particular soil or rock found at the site.

Various levels of accuracy in determining travel time can be used. These may range from first order
estimates to precisely measured onsite values.

Using the depth of a known target (trenches, road cuts or buried pipes/road culverts can provide a
radar target of known depth), a radar record taken over the known target, and a time scale provided
by the pulse generator will provide basic calibration record. From these data, a two-way travel time
can be accurately determined at the given target location. Because this approach may give accurate

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
13 of 17

calibration at the specific site, it must be assumed that conditions in other areas to be surveyed are
the same as in the calibration areas. If they are not, errors will occur in determining depths.

If significant changes in soil type or moisture content occur with depth, travel time will not be the
same throughout the vertical radar profile, and the vertical radar depth scale may be non-linear. Such
a condition is common, and occurs whenever an unsaturated zone exists over a saturated zone.

Procedures

Check the time scale of the GPR unit regularly for accuracy. This can be done either on or
off the site by placing the GPR unit at a known distance from the ground, a wall, etc., and
measuring the two-way travel time to that reflecting surface in the air. The velocity of
electromagnetic waves in air is 1 foot per nanosecond (3 x 10s meters per second). The
following equation shall be used:

t = 2d/c

Where:

t = two-way travel time from antenna to the surface (nanoseconds)
d = distance of antenna to the surface (feet)
c = velocity of light in air, (1 foot/nanosecond)

Prior to conducting a survey, conduct a GPR traverse over a buried object of known depth (if
available). From the two-way travel time and the measured burial depth of the object, the
average electromagnetic wave velocity in soil can be calculated from the following equation:

V = 2d/t

The average dielectric constant of the soil is then calculated using:

Er = c^/v^

Where:

Er = average relative dielectric constant of soil (unitless)
c = velocity of light in air (1 foot/nanosecond)

v = average electromagnetic wave velocity of the soil (feet/nanosecond)

Note: The equation above assumes a soil with a relative magnetic permeability of 1.
Exercise technical judgment such that soil velocity and relative dielectric constant
values are reasonable with respect to existing site conditions.

A short GPR traverse shall be repeated twice daily over a known feature prior to and after
conducting daily operations. Exercise technical judgment to ensure that variations between
repeat readings are due to changing soil conditions rather than the electronics.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
14 of 17

5.4.2.4 Metal Detection - Magnetometers

Magnetometers are designed to provide measurements of the earth's magnetic field. In hazardous
waste site investigations, magnetometers are invaluable for detecting buried drums and for
delineating the boundaries of areas containing ferrous metallic debris.

Check the proposed date of the magnetic survey for solar flares to ensure that anticipated
background conditions do not occlude data collection (Bureau of Standards, Boulder, CO,
Goldendale, WA).

Obtain a daily background reading in the immediate vicinity of the site to be surveyed. This
reading should be outside the influence of all sources of cultural magnetic fields (e.g., power
lines, pipeline). Exercise technical judgment such that the background reading is reasonable
with regard to published data for the total magnetic field intensity at the site latitude and
longitude. This daily background reading should repeat to within reasonable diurnal
variations in the earth's magnetic field.

Take sequential readings twice daily, before and after normal magnetic surveying operations.
Take these readings (within 10 seconds of each other) at any location on site, distant from
cultural magnetic fields, and record them in the field notebook. Two or three sequential
readings should be sufficient. In the absence of magnetic storms (sudden and violent
variations in the earth's magnetic field), the readings should compare within 0.1 to a few
tenths of a gamma. Variations during magnetic storms may approach 1 gamma.

Take base station readings so that the efforts of diurnal variation in the earth's magnetic field
may be removed from the data. Magnetic storms can be detected if the base station sampling
frequency is high enough. It may be necessary to postpone operations during magnetic
storms and resume them when they have passed. Identification of such periods of rapid
synoptic variation may be documented at a permanent base stations set up on site where
continuous readings are automatically recorded every 10 to 15 minutes. Alternatively,
readings may be manually recorded at base stations during the survey every 45 to
60 minutes.

Use of automatic recording magnetometers requires recording the magnetometer readings
for the first and last station of each traverse in a field notebook. At the end of the day,
compare the data recorded in the field notebook with data from the automatic recording
device. Data recorded in the field notebook should be within 1 gamma of the values derived
from the recording device. It is recommended to transfer the data onto hard copies from the
recording device on a daily basis.

Total field measurements may be corrected for these time variations by employing a reference base
station magnetometer; changes in the earth's field are removed by subtracting fixed base station
readings from the moving survey data. Gradiometers do not require the use of a base station, as they
inherently eliminate time variation in the data.

5.4.2.5 SP Profiling

This method is different from other electrical techniques in that no artificial current source is used to
inject a signal into the ground; only the naturally occurring voltage potentials are measured between

Procedures

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
15 of 17

surface stakes. These natural voltages are produced by chemical oxidation reactions between
groundwater and different soil and mineral types.

SP equipment consists of a digital, high-impedance volt meter; two porous pot electrodes; and
cables. SP equipment should have a resolution of at least +2 millivolts (mv) and accuracy within
+ 10 mv.

Calibrate equipment per the manufacturer's specifications. At a minimum, calibrate the
equipment twice daily, once prior to beginning operations and once at the end of daily
operations. Record calibration results in the field log.

Each SP station shall be identified with a unique number and located on a site layout
drawing. Record profiling results for each station using a field data form that includes the
time of each measurement. Annotate the form to show any natural or cultural features near
or between the SP stations.

Establish a base station for the purpose of measuring instrument drift during the SP profiling
activities. Take the instrument to the base station routinely during the day, and obtain
readings from one location at the base station. Obtain base station readings at the beginning
and end of each day and at interim intervals not exceeding 4 hours in duration.

Reduce data by adjusting measurements obtained for instrument drift. Base station readings
are plotted as a separate curve from profiling station measurements. The drift is interpolated
(straight line) between base station readings as a function of time and the appropriate drift
correction is subtracted from each profiling station measurement. Reduced data are used for
interpretation.

Interpret data by plotting reduced data (either for linear cross-sections of the study area or as
surface contours over the study area surface). Anomalies are identified from these plots, and
inferences regarding their sources are developed.

5.4.3 Post-Operations

Geophysical personnel working at a site should follow standard hazardous waste site protocols. In
many cases, the geophysical survey may precede services that may result in personnel contact with
hazardous waste/materials. Geophysical personnel at all sites should follow standard hazardous
waste site decontamination procedures.

5.5 Data Reduction/Data Interpretation

Geophysical surveys typically require significant data reduction and processing. The exact
methodology depends upon the purpose, scope, and type of survey.

Data interpretation and presentation reports should include the following:

Data reduction technique

Data processing steps

Technical basis for data processing

Procedures

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
16 of 17

Survey location data

Site base map showing survey location or transects
Dates and times of survey
Interpretation results

Theoretical assumptions for the interpretation
Equipment used

Data format (digital format, ASCII, SEG B.,)

5.6 Quality Assurance/Quality Control

The following QA procedures apply to all geophysical instrumentation and their use during data
acquisition.

Document all data transmittals on standard forms supplied by the geophysical subcontractor.
Copies of these forms will be maintained with the field files on site.

Operate geophysical instrumentation in accordance with operating instructions supplied by
the manufacturer, unless otherwise specified in the work plan.

Monitor battery voltage levels for all instruments each day throughout the survey. Charge or
replace battery packs when voltage levels fall below the recommended level specified by
geophysical equipment manufacturers.

6.	Records

The FM is responsible for documenting all field activities in the field notebook. The FM should also
oversee all subcontractor activities and ensure that their documentation is complete. The specific
procedures used in the field shall be documented in the site characterization report or similar
deliverable.

7.	Health and Safety

Field Personnel shall perform work in accordance with the current (or as contractually obligated)
United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2008) and site-specific health and safety plan.

8.	References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/uip_qapp_vl_0305.pdf.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

Dobrin, M. B. and C. H. Savitt. 1988. Introduction to Geophysical Prospecting. McGraw-Hill.

-------
NAVFAC Pacific ER Program
Geophysical Testing

Procedure Number:
Revision Date:
Page:

i-B-2
May 2015
17 of 17

Sheriff, R. E. 1991. Encyclopedic Dictionary of Exploration Geophysics. Tulsa, OK: Society of
Exploration Geophysics.

Telford, W. M., L. P. Geldart, R. E. Sheriff, D. A. Keys. 1998. Applied Geophysics. Cambridge
University Press.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

9. Attachments

None.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Surface Water Sampling

Procedure Number:

Revision:

Page:

i-B-5
May 2015
1 of 7

Surface Water Sampling

1.	Purpose

The purpose of this standard operating procedure is to establish standard protocols for use in
sampling surface water by all United States Navy Environmental Restoration (ER) Program, Naval
Facilities Engineering Command (NAVFAC), Pacific personnel.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the most current version of the Uniform Federal Policy-Quality
Assurance Project Plan (DoD 2005). As professional guidance for specific activities, this procedure
is not intended to obviate the need for professional judgment during unforeseen circumstances.
Deviations from this procedure while planning or executing planned activities must be approved and
documented by the following prime contractor representatives: the CTO Manager and the Quality
Assurance (QA) Manager or Technical Director. A Navy project representative (i.e. Remedial
Project Manager or QA manager) shall also concur with any deviations.

3.	Definitions

None.

4.	Responsibilities

The prime contractor CTO Manager is responsible for ensuring that all project field personnel follow
these procedures when sampling surface water. The CTO Manager is responsible for ensuring that all
personnel involved in sampling and/or testing shall have the appropriate education, experience, and
training to perform their assigned tasks as specified in Chief of Naval Operations Instruction 5090.1,
under Specific Training Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The Field Manager is responsible for ensuring that all project field staff follow these procedures.

Field sampling personnel are responsible for the implementation of this procedure.

5.	Procedures

Surface water bodies that could be affected by a release from an investigation site may be selected
for sampling. This procedure describes sample collection methods for a surface water sampling
program.

-------
NAVFAC Pacific ER Program
Surface Water Sampling

Procedure Number:

Revision:

Page:

i-B-5
May 2015
2 of 7

5.1 Selection of Sampling Techniques

Proper selection of sampling points and collection methodology are essential to meeting the
objectives of a surface water sampling program. The data quality objectives and the conceptual site
model should be used to determine all sampling methods and parameters. Sampling points should be
selected for collection of surface water samples on the basis of characteristics of the surface water
body to be monitored, the location of the body of surface water, and its hydrologic boundaries with
respect to the site. Other considerations include the contaminants of concern, logistical
considerations, such as access to the surface water body, the direction of flow, and determination of a
background location.

Methods of collecting surface water samples vary from hand sampling procedures at a single point to
sophisticated, multipoint sampling techniques. The number and type of samples to be collected
depends on the characteristics of the body of water, the amount of suspended sediment that a moving
body carries, the size of the discharge area at the site, and other factors. Multipoint sampling
techniques apply to larger bodies of water; the samples are composited to provide a more
representative sample.

Whenever possible, the sampling device, either disposable or constructed of a nonreactive material,
should hold at least 500 milliliters to minimize the number of times the liquid must be disturbed, thus
reducing agitation of any sediment layers. A 1-liter polypropylene or stainless steel beaker with a
pour spout and handle works well. Any sampling device might contribute contaminants to a sample.
The correct sampling device will not compromise the integrity of the sample and will give the
desired analytical results.

5.1.1	Shallow Water Body Surface Water Sample Collection

A dip or grab sample is appropriate for a small body of water, or for collecting near-surface samples
in a larger surface water body. The sampling method involves filling a sample container by
submerging it either just below the surface, or by lowering the container to a desired depth by using a
weighted holder. For shallow bodies of surface water, hold the sample container carefully just
beneath the water surface to avoid disturbing the streambed and stirring the sediment. Position the
container's mouth so that it faces upstream, while the sampling personnel are standing downstream.
Any preservative added to the sample should be added after sample collection to avoid loss of
preservative. Alternatively, a transfer device may be dipped into the water, and then the contents
transferred to the appropriate container containing the preservative. For near-surface sample
collection in a large surface water body, a pond sampler may be used if an extended reach is required
to collect a representative sample. A pond sampler consists of a single use sample container attached
to a telescoping, heavy-duty, aluminum pole via an adjustable clamp attached to the end. The
collection technique for shallow surface water samples can be used for near-surface samples in a
large surface water body.

5.1.2	Deep Surface Water Sample Collection

For deeper surface water bodies, either sample containers or transfer devices may be used to collect a
sample. A weighted holder that allows either a sample transfer device or a sample container to be
lowered, opened for filling, closed, and returned to the surface is suggested for sampling deeper
surface water bodies. This is because concentrations of constituents near the surface of a deeper body
of surface water might differ from the total concentration distributed throughout the water column
cross section and thus a surface sample would not be representative of the water body. An open

-------
NAVFAC Pacific ER Program
Surface Water Sampling

Procedure Number:

Revision:

Page:

i-B-5
May 2015
3 of 7

container that is lowered and raised to the surface at a uniform rate so that the bottle is just filled on
reaching the surface is appropriate for deeper stagnant water bodies, however this method does not
collect a truly representative sample in deeper flowing surface water bodies.

Kemmerer Samplers. Collect samples near the shore unless sampling from a boat is feasible and
permitted. If a boat is used, the body of water should be cross-sectioned, and samples should be
collected at various depths across the water in accordance with the specified work plan. For this type
of sampling, use a weighted-bottle sampler to collect samples at any predetermined depth. The
sampler consists of a glass bottle, a weighted sinker, a bottle stopper, and a line that is used to open
the bottle and to lower and raise the sampler during sampling. The sampler can be either fabricated
or purchased. The general procedure for using the sampler is as follows:

1.	Assemble the weighted bottle sampler.

2.	Gently lower the sampler to the desired depth so as not to remove the stopper prematurely.

3.	Pull out the stopper with a sharp j erk of the sampler line.

4.	Allow the bottle to fill completely, as evidenced by the cessation of air bubbles.

5.	Raise the sampler and cap the bottle.

6.	Wipe the bottle clean. The bottle can also be used as the sample container.

Teflon Bailers: Teflon bailers have also been used to collect samples in deep bodies of water. When
the use of Teflon bailers is deemed appropriate for sampling water from a specific depth, the bailers
shall be equipped with a check valve that closes during sample retrieval.

Peristaltic Pump: Another method of extending the reach of sampling efforts is to use a small
peristaltic pump. In this method, the sample is drawn through heavy-wall Teflon tubing and pumped
directly into the sample container. This system allows the operator to reach into the liquid body,
sample from depth, or sweep the width of narrow streams. However, use of the peristaltic pump is
restricted to a maximum depth of 20 to 24 feet due to the physical constraints associated with
vacuum pumps.

If medical-grade silicon tubing is used in the peristaltic pump, the system is suitable for sampling
almost any analyte, including most organics. Some volatile stripping may occur; due to the relatively
high flow rate of the pump. Therefore, avoid pumping methods for sampling volatile organics.
Battery-operated peristaltic pumps are available and can be easily carried by hand or with a shoulder
sling, as needed. It is necessary in most situations to change both the Teflon suction line and the
silicon pump tubing between sampling locations to avoid cross contamination. This action requires
maintaining a sufficiently large stock of material to avoid having to clean the tubing in the field.

Peristaltic pumps work especially well for sampling large bodies of water when a near-surface
sample will not sufficiently characterize the body as a whole. It is capable of lifting water from
depths in excess (but not much in excess) of 21 feet. This lift ability decreases somewhat with
higher-density fluids and with increased wear on the silicone pump tubing. Similarly, increases in
altitude will decrease the pump's ability to lift from depth. When sampling a liquid stream that
exhibits a considerable flow rate, it may be necessary to weight the bottom of the suction line.

-------
NAVFAC Pacific ER Program
Surface Water Sampling

Procedure Number:

Revision:

Page:

i-B-5
May 2015
4 of 7

Use the following procedures for collecting samples using peristaltic pumps:

1.	Install clean, medical-grade silicone tubing in the pump head, per the manufacturer's
instructions. Allow sufficient tubing on the discharge side to facilitate convenient
dispensation of liquid into sample bottles but only enough on the suction end for attachment
to the intake line. This practice will minimize sample contact with the silicone pump tubing.
(Some types of thinner Teflon tubing may be used.)

2.	Select the length of suction intake tubing necessary to reach the required sample depth and
attach it to the tubing on the intake side of the pump. If necessary, a small weight composed
of relatively inert material, which will not react with anticipated chemicals, may be used to
weight the intake tubing. Heavy-wall Teflon of a diameter equal to the required pump tubing
will suit most applications. (A heavier wall will allow for a slightly greater lateral reach.)

3.	If possible, allow several liters of sample to pass through the system before actual sample
collection. Collect this purge volume, and then return it to the source (i.e., surface water)
after the sample aliquot has been collected.

4.	Fill necessary sample bottles by allowing pump discharge to flow gently down the side of
bottle with minimal entry turbulence. Cap each bottle as it is filled.

5.	Preserve the sample, if necessary, following guidelines in the work plan. In most cases, place
preservatives in sample containers before sample collection to avoid overexposure of
samples and overfilling of bottles during collection.

6.	Check that a Teflon liner is present in the cap, if required. Secure the cap tightly. Tape the
cap to the bottle, and then date and initial the tape. The tape will serve as a custody seal.

7.	Label the sample bottle with an appropriate tag using a solvent-free marker. Be sure to label
the tag carefully and clearly, addressing all the categories or parameters. Record the
information in the field logbook, and complete the chain-of-custody documents.

8.	Place the properly labeled sample bottle in an appropriate carrying container.

9.	Allow the system to drain thoroughly, and then disassemble and decontaminate it.

5.2 Transfer Devices

Samples from various locations and depths can be composited if project quality objectives indicate
that it is appropriate; otherwise, collect separate samples. Identify approximate sampling points on a
sketch of the water body. Use the following procedures for collecting samples using transfer devices:

1.	Submerge a stainless steel dipper or other suitable device, causing minimal disturbance to
the surface of the water. Note the approximate depth and location of the sample source
(e.g., 1 foot up from bottom or just below the surface).

2.	Allow the device to fill slowly and continuously.

3.	Retrieve the dipper or device from the surface water with minimal disturbance.

4.	Remove the cap from the sample bottle and slightly tilt the mouth of the bottle below the
dipper or device edge.

5.	Empty the dipper or device slowly, allowing the sample stream to flow gently down the side
of the bottle with minimal entry turbulence.

-------
NAVFAC Pacific ER Program
Surface Water Sampling

Procedure Number:

Revision:

Page:

i-B-5
May 2015
5 of 7

6.	Continue delivery of the sample until the bottle is almost filled. Check all procedures for
recommended headspace for expansion.

7.	If necessary, preserve the sample according to guidelines in the work plan. In most cases,
place preservatives in sample containers before sample collection to avoid overexposure of
samples and overfilling of bottles during collection.

8.	Check that a Teflon liner is present in the cap, if required. Secure the cap tightly. Tape the
cap to the bottle using solvent-free tape, and then date and initial the tape. The tape will
serve as a custody seal.

9.	Label the sample bottle with an appropriate sample tag using a solvent-free marker. Be sure
to label the tag carefully and clearly, addressing all the categories or parameters. Record the
information in the field logbook, and complete the chain-of-custody form.

7. Dismantle the sampler, wipe the parts with terry towels or rags, and store them in plastic
bags for subsequent disposal. Follow all instructions for proper decontamination of
equipment and personnel.

Use the following procedures for collecting samples using peristaltic pumps:

1.	Install clean, medical-grade silicone tubing in the pump head, per the manufacturer's
instructions. Allow sufficient tubing on the discharge side to facilitate convenient
dispensation of liquid into sample bottles but only enough on the suction end for attachment
to the intake line. This practice will minimize sample contact with the silicone pump tubing.
(Some types of thinner Teflon tubing may be used.)

2.	Select the length of suction intake tubing necessary to reach the required sample depth and
attach it to the tubing on the intake side of the pump. If necessary, a small weight composed
of relatively inert material, which will not react with anticipated chemicals, may be used to
weight the intake tubing. Heavy-wall Teflon of a diameter equal to the required pump tubing
will suit most applications. (A heavier wall will allow for a slightly greater lateral reach.)

3.	If possible, allow several liters of sample to pass through the system before actual sample
collection. Collect this purge volume, and then return it to the source (i.e., surface water)
after the sample aliquot has been collected.

4.	Fill necessary sample bottles by allowing pump discharge to flow gently down the side of
bottle with minimal entry turbulence. Cap each bottle as it is filled.

5.	Preserve the sample, if necessary, following guidelines in the work plan. In most cases, place
preservatives in sample containers before sample collection to avoid overexposure of
samples and overfilling of bottles during collection.

6.	Check that a Teflon liner is present in the cap, if required. Secure the cap tightly. Tape the
cap to the bottle, and then date and initial the tape. The tape will serve as a custody seal.

7.	Label the sample bottle with an appropriate tag using a solvent-free marker. Be sure to label
the tag carefully and clearly, addressing all the categories or parameters. Record the
information in the field logbook, and complete the chain-of-custody documents.

8.	Place the properly labeled sample bottle in an appropriate carrying container.

9.	Allow the system to drain thoroughly, and then disassemble and decontaminate it.

-------
NAVFAC Pacific ER Program
Surface Water Sampling

Procedure Number:

Revision:

Page:

i-B-5
May 2015
6 of 7

Multipoint sampling techniques that represent both dissolved and suspended constituents and both
vertical and horizontal distributions are applicable to larger bodies of water. Subsequent to sample
collection, multipoint sampling techniques may require a compositing and sub-sampling process to
homogenize all the individual samples into the number of subsamples required to perform the
analyses of interest. Homogenizing samples is discouraged for samples collected for volatile organic
analysis, because aeration causes a loss of volatile compounds. If collection of composite samples is
required, then include the procedure for compositing in the project-specific work plan.

The sampling devices selected must not compromise sample integrity. Collect samples with either
disposable devices, or devices constructed of a nonreactive material, such as glass, stainless steel, or
Teflon. The device must have adequate capacity to minimize the number of times the liquid must be
disturbed, reducing agitation of any sediment layers. Further, the device must be able to transfer the
water sample into the sample container without loss of volatile compounds. A single- or
double-check valve or stainless steel bailer made of Teflon equipped with a bottom discharging
device may be used.

All equipment used for sample collection must be decontaminated before and after use in accordance
with Procedure I-F, Equipment Decontamination.

5.3 Typical Field Sampling supplies and Equipment/Apparatus

Sampling	supplies

•	Work Plan

•	Maps/Plot plan

•	Tape measure

•	Survey stakes, flags, or buoys

•	Camera

•	Stainless steel, plastic, or other appropriate composition (e.g., Teflon) bucket

•	Laboratory supplied sampling containers

•	Ziploc plastic bags for samples, and sample jars

•	Logbook

•	Labels

•	Chain of Custody forms

•	Site description forms

•	Cooler(s)

•	Ice

Equipment/Apparatus

•	Decontamination supplies/equipment

•	Spade or shovel

-------
NAVFAC Pacific ER Program
Surface Water Sampling

Procedure Number:

Revision:

Page:

i-B-5
May 2015
7 of 7

•	Spatula

•	Scoop

•	Trowel

•	Task-specific surface water sampling equipment

6.	Records

During the completion of sampling activities, fill out the sample logbook and transmit forms to the

CTO Manager for storage in project files.

7.	Health and Safety

Field Personnel shall perform work in accordance with the current (or as contractually obligated)

United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1

(USACE 2008) and site-specific health and safety plan.

8.	References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-F, Equipment Decontamination.

9. Attachments

None.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
1 of 44

Monitoring Well Installation and Abandonment

1.	Purpose

This standard operating procedure describes the methods to be used by the United States (U.S.) Navy
Environmental Restoration (ER) Program, Naval Facilities Engineering Command (NAVFAC),
Pacific personnel during the installation of groundwater monitoring wells. It describes the
components of monitoring well design and installation and sets forth the rationale for use of various
well installation techniques in specific situations.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the Uniform Federal Policy-Quality Assurance Project Plan
(DoD 2005). As professional guidance for specific activities, this procedure is not intended to
obviate the need for professional judgment during unforeseen circumstances. Deviations from this
procedure while planning or executing planned activities must be approved and documented by the
following prime contractor representatives: the CTO Manager and the Quality Assurance (QA)
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

3.	Definitions

3.1	Filter Pack

Filter pack is sand or gravel that is smooth, uniform, clean, well-rounded, and siliceous. It is placed
in the annulus of the well between the borehole wall and the well screen to prevent formation
materials from entering the well and to stabilize the adjacent formation.

3.2	Annulus

The annulus is the downhole space between the borehole wall and the well casing and screen.

3.3	Bridge

An obstruction in the drill hole or annulus. A bridge is usually formed by caving of the wall of the
well bore, by the intrusion of a large boulder, or by filter pack materials during well completion.
Bridging can also occur in the formation during well development.

3.4	Grout

Grout is a fluid mixture of cement and water that can be forced through a pipe and emplaced in the
annular space between the borehole and casing to form an impermeable seal. Various additives, such
as sand, bentonite, and polymers, may be included in the mixture to meet certain requirements.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
2 of 44

3.5 Sieve Analysis

Sieve analysis is the evaluation of the particle-size distribution of a soil, sediment, or rock by
measuring the percentage of the particles that will pass through standard sieves of various sizes.

4.	Responsibilities

CTO Managers are responsible for issuing WPs that reflect the procedures and specifications
presented in this procedure. Individual municipalities, county agencies, and, possibly, state
regulatory agencies enforce regulations that may include well construction and installation
requirements. The CTO Manager shall be familiar with current local and state regulations, and
ensure that these regulations are followed. Regulations are subject to constant revision. Every effort
should be made to stay informed of these changes through contact with the agencies that oversee
work in specific project areas, prior to initiation of field activities. The CTO Manager or designee
shall review all well construction logs on a minimum monthly basis. The CTO Manager is
responsible for ensuring that all personnel involved in monitoring well installation and abandonment
have the appropriate education, experience, and training to perform their assigned tasks as specified
in Chief of Naval Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The Field Manager (FM) is responsible for direct supervision of the installation of monitoring wells
and ensuring that procedures and specifications are implemented in the field. The qualifications for
the FM include a degree in geology, hydrogeology, civil/geotechnical/environmental engineering, or
equivalent with at least 2 years of field experience in the installation of monitoring wells.

Field sampling personnel are responsible for the implementation of this procedure.

The onsite geologist/hydrogeologist/engineer is expected to obtain a description of the lithologic
samples obtained during the excavation and construction of a monitoring well. These data are often
required to provide guidance regarding the installation of specific components of the monitoring
well. Guidance for lithologic sample collection and sample description is contained within
Procedure I-B-l, Soil Sampling.

5.	Procedures

5.1 Considerations For Munitions and Explosives of Concern

Potential Munitions and Explosives of Concern (MEC) hazards may be encountered in any area
formerly or currently occupied or used by the Department of Defense (DoD). MEC hazards may
occur on the ground surface, in the subsurface, and within bodies of water, and may not always be
readily observable, or identifiable. As a result, whether or not munitions-related activities ever
occurred on the specific work area or within waters in which Navy operations/activities will take
place, special care should always be taken when conducting field operations, especially intrusive
activities, in the event that MEC may be encountered.

If the site is currently recognized as belonging in the Military Munitions Response Program and has
a current, Naval Ordnance Safety and Security-accepted, site-specific Explosives Safety Submission

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
3 of 44

(ESS) (per DON 2010), then field activities, especially intrusive activities, shall adhere to the safety
procedures outlined within the ESS.

If suspected MEC is encountered on an active DoD installation, immediately notify your supervisor,
DoD Point of Contact, and installation Point of Contact, who will contact and facilitate military
Explosive Ordnance Disposal response.

5.2	Background Information

The primary objectives of installing a monitoring well at a site are: to observe groundwater levels
and flow conditions; to obtain samples for determining groundwater quality; and to evaluate the
hydraulic properties of water-bearing strata. To achieve these objectives, it is necessary to satisfy the
following criteria:

Construct the well with minimum disturbance to the formation.

Construct the well with materials that are compatible with the anticipated geochemical
environment.

Properly complete the well in the desired zone.

Adequately seal the well with materials that will not interfere with the collection of
representative water samples.

Sufficiently develop the well to remove drilling fluids or other additives or conditions
associated with drilling, and provide unobstructed flow to the well.

The proper design and construction of monitoring wells requires an understanding of site geology
and hydrogeology, and knowledge of contaminant transport in subsurface materials.

A significant difference between monitoring wells and production or "water" wells is that the intake
section of monitoring wells is often purposely completed in a zone of poor water quality and/or poor
yield. The quality of water entering a monitoring well can vary from drinking water to a hazardous
waste or leachate. In contrast, production wells are normally designed to efficiently obtain water
from highly productive zones containing good quality water. The screen of a monitoring well often
extends only a short length (typically 10 feet or less) to monitor hydraulic conditions within, and
obtain water samples from, selected water-bearing intervals. In contrast, water wells are often
designed to obtain economic quantities of water from multiple zones of water-bearing strata.

5.3	Monitoring Well Design Considerations

The following information was compiled from a number of technical references. For additional
information related to monitoring well installation, consult the references listed in Section 8.

5.3.1 Well Placement

Select the location of a monitoring well according to the purpose of the monitoring program, which
will vary among different sites and may include detection of contaminants in groundwater,
verification of contaminant migration predictions, the monitoring of leachate at a landfill site, or
remediation of a contaminated site. Each of these purposes will require a specialized array of
monitoring locations and completion intervals, and a specific sampling program. Therefore, design
the monitoring well network to satisfy the needs of the particular situation.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
4 of 44

Determine the position of a monitoring well in a contaminant flow path for a monitoring effort based
on the interpretation of preliminary data. These data shall be sufficient to facilitate identification of
potential contaminant sources. Also consider site history, topography, climate, surface hydrology,
and the location of nearby pumping wells.

Design the layout of the groundwater monitoring network following preliminary evaluation of the
approximate direction of groundwater flow. A minimum of three wells is necessary to estimate local
hydraulic gradients. Ideally, at least one well will be located hydraulically upgradient, and two or
more wells strategically located hydraulically downgradient of each potential contaminant source.
Determination of the horizontal and vertical extent of a contaminant plume is often an iterative
process requiring the installation and sampling of wells in several phases.

Install monitoring wells hydraulically downgradient and as close as physically possible to the areas
of suspected contamination in order to immediately detect releases from a hazardous waste site.
Locate additional monitoring wells based on the interception of potential groundwater flow paths and
direction of contaminant migration.

The placement of groundwater monitoring wells shall also consider the three-dimensional nature of
groundwater flow. Significant vertical gradients and heterogeneous and/or anisotropic hydraulic
conditions may exist at a site. Thus, the direction of groundwater flow may not necessarily coincide
with the apparent horizontal gradient observed by the triangulation provided by three monitoring
wells. Determine the completion intervals of existing wells prior to the calculation of groundwater
gradient directions. Consider temporal/seasonal groundwater flow conditions if the monitoring well
network is located near existing active well fields, near tidal zones, or near ephemeral surface water
(e.g., canals, dry river beds).

5.3.2 Well Depth and Screened Interval

A detailed understanding of the site stratigraphy, including both horizontal and vertical extent of
geologic formations, is necessary to identify zones of different permeabilities, and discontinuities,
such as bedding planes, fractures, or solution channels. Groundwater flow and/or contaminant
transport beneath the site preferentially occur in the more permeable zones. Equally important is the
identification of relatively low permeability zones that may impede migration of contaminants. The
occurrence and movement of groundwater in the subsurface is closely related to lithology. Thus,
geologic conditions will influence the location, design, and methods used to locate and install
monitoring wells.

The depth of a monitoring well is determined by the depth of one or more water-bearing zones that
are to be monitored. For example, if preliminary soil borings indicate that multiple water-bearing
zones are present at a site, and it is believed that zones other than the uppermost zone may be
impacted by surface contamination, a well should be completed in each individual water-bearing
zone encountered. Where two or more saturated zones occur beneath a site, and the intent of the
monitoring program is to monitor water quality in the lower zone, the monitoring well will generally
require surface casing to isolate the upper water-bearing zone from the deeper zone prior to drilling
into the deeper zone.

In multiple aquifer systems, highly variable conditions may occur. For example, an overlying
unconfined aquifer may be contaminated, whereas the underlying confined aquifer may not contain
contaminants. Exercise extreme care to ensure that the installation/completion of monitoring wells

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
5 of 44

does not cause cross-contamination of the aquifers. In these cases, it may be preferable to install
surface casing through the contaminated aquifer to minimize the possibility of cross-contamination
to the lower aquifer system.

Characteristics of lithologic materials encountered at the site, such as the degree of consolidation and
grain size, also influence the type of well completion. In unconsolidated alluvial deposits, screened
well intakes are typically used. An emplaced filter pack, consisting of well-sorted, clean, inert silica
sand with a grain size and well screen slot size appropriate for the formation, typically is used to
filter out fine-grained materials present within formations encountered in the borehole. Where
permeable, consolidated formations are present, casing may be extended through overlying
unconsolidated deposits and the well may be completed with a section of open borehole in the
consolidated water-bearing zone. Even in these cases, however, fine-grained materials may enter the
well through fractures, and if severe enough, an artificial filter pack and screened intake may be
required. Also, many regulatory agencies require a screened interval installed with filter pack for all
well completions.

Placement of the screened interval depends primarily on two factors: the interval to be monitored and
the type of contaminants. The desired interval to be monitored shall dictate the interval to be
screened. Determine which stratigraphic horizons represent potential pathways for contaminant
migration by the site characterization. Short screened sections provide more specific data on the
vertical distribution of contaminants and hydraulic head, while long screen intervals can result in a
cumulative dilution of contamination in one zone with uncontaminated groundwater in another zone,
as well as less specific information on hydraulic head. In addition, a long screened interval could
potentially create vertical conduits that might result in cross-contamination.

Consider the type of contaminants involved prior to well installation. Contaminants that have a
density less than water migrate differently than contaminants with a density equal to or greater than
water. For example, if the contaminant in an unconfined aquifer has a density lower than water, such
as diesel or gasoline, it is important to ensure that the screened interval of the well extends above the
maximum seasonal elevation of the water table. Doing so facilitates an accurate determination of
apparent thickness of free product in a monitoring well. In general, the screen shall extend 3 to 5 feet
above the highest anticipated level of the water table when monitoring the upper portions of an
unconfined aquifer.

Conversely, if the contaminant of concern has a density higher than water, such as trichloroethene
(TCE), the screened interval of one or more monitoring wells should be installed just above the
lower confining bed of a potentially impacted aquifer. TCE may be transported at high
concentrations as a dense, nonaqueous phase liquid (DNAPL) near the source area, and migrate
along the top of a confining bed at the base of an impacted aquifer.

Give special attention to interpretation of site stratigraphy when assessing DNAPL, particularly with
respect to dipping beds, as it is possible for DNAPLs to effectively move hydraulically upgradient if
low permeability perching horizons dip in a direction opposite the hydraulic gradient. This type of
situation is important to consider when selecting monitoring well locations.

If time and budget allow, correlate conventional borehole geophysical methods and continuous cores
of soil samples to yield a more complete stratigraphic characterization. A continuous profile of
borehole conditions is compared to field observations and is used to select screened intervals.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
6 of 44

5.3.3 Well Permitting

All wells shall be permitted in accordance with the regulations of the jurisdiction where well
installation is occurring, if this is Navy policy for the region of activity. Contact local authorities
prior to establishing well construction requirements for the project.

The permit procedure may require permit fees, site inspections, and an application signed by a
registered professional geologist or engineer. Permit requirements may impact field schedules and
budgets. The driller may also be required by law to be licensed and bonded. Provide documentation
that all legal requirements have been met to the appropriate agencies prior to the installation of a
monitoring well.

5.4 Selection of Drilling Method

Monitoring well installation at hazardous waste sites may involve drilling through or near hazardous
materials, in areas where the extent of contamination is unknown, or through more than one geologic
material or aquifer. Use of any drilling method at a hazardous waste site involves an element of risk
related to the potential spread of contamination or creation of a pathway through which contaminants
can migrate. Selection of a method most appropriate for site-specific conditions is essential to
minimize these risks. Table I-C-l-1 provides an interpretation of how geologic conditions may
influence the selection of a particular drilling method.

Most drill rigs use gasoline or diesel fuel, as well as hydraulic fluid during operation. Because these
fluids are all potential contaminants, it is important to protect the drill hole and immediate area from
these substances. Whenever leaking fluid from the drill rig is detected, drilling operations shall cease
as soon as practical following stabilization of the drill stem, and the rig shall be moved to a safe area
to be repaired.

Table l-C-1 -1: Relative Performance of Different Drilling Methods in Various Types of Geologic
Formations; Commonly Utilized Drilling Methods

Type of
Formation

Auger-
Hollow
Stem

Rotary
Bucket
Auger*

Rotary
with
Fluids
(foam,
mud)*

Air
Rotary

Air Rotary
with
Casing
Hammer

Down the
Hole Air
Hammer

Dual
Tube/
Casing
Hammer

Coring

Reverse
Rotary
with
Fluids*

Reverse
Rotary
with Dual
Tube

Direct
Push

Loose sand
and gravel

G

P

P-G

NR

E

NR

E

NR

P-E

E

E

Loose
boulders in
alluvium

P

P-G

G

NR

E

NR

P

NR

P

G

NR

Clay, silt

E

G

E

NR

E

NR

E

P-G

E

E

G

Shale

P

NR

E

P

E

NR

NR

E

E

E

NR

Sandstone

P

NR

G

E

NR

NR

NR

E

G

E

P

Limestone
with chert

NR

NR

G

E

NR

E

NR

E

G

G

NR

Limestone
with and
without
fractures

NR

NR

G-E

E

NR

E

NR

E

P-E

E

P

Limestone,

NR

NR

P-G

P-G

NR

E

NR

E

NR

E

NR

cavernous























-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
7 of 44

Type of
Formation

Auger-
Hollow
Stem

Rotary
Bucket
Auger*

Rotary
with
Fluids
(foam,
mud)*

Air
Rotary

Air Rotary
with
Casing
Hammer

Down the
Hole Air
Hammer

Dual
Tube/
Casing
Hammer

Coring

Reverse
Rotary
with
Fluids*

Reverse
Rotary
with Dual
Tube

Direct
Push

Dolomite

NR

NR

E

E

NR

E

NR

E

E

E

NR

Basalts-thin
layers in
sedimentary
rocks

P

NR

G

E

NR

NR

NR

E

G

E

P

Tuff

P

NR

G

E

NR

E

NR

E

G

G

NR

Basalts-thick
layers

NR

NR

P

G

NR

E

NR

E

G

G

NR

Basalts-highly
fractured

NR

NR

NR

P

NR

G

NR

E

NR

G

NR

Metamorphic
rocks

NR

NR

NR-P

G

NR

E

NR

E

G

G

NR

Granite

NR

NR

NR-P

E

NR

E

NR

E

G

G

NR

E	Excellent

G	Good

NR Not Recommended
P	Poor

* Cannot be used for analytical soil sampling

** Procedure l-H, Direct-Push Sampling Techniques discusses protocol associated with direct push applications.

The following sections discuss commonly used drilling methods and their applicability to installation
of monitoring wells. Regardless of the drilling method selected, decontaminate all drilling equipment
using Procedure I-F, Equipment Decontamination. Follow these procedures before use and between
borehole locations to prevent cross-contamination. In addition to selecting the proper drilling
technique, take other precautions to prevent distribution of any existing contaminants throughout the
borehole.

5.4.1 Hollow-stem Continuous-flight Auger

Hollow-stem continuous-flight auger (HSA) is the most frequently employed method used in the
environmental industry for the drilling and installation of shallow monitoring wells in
unconsolidated materials. Drilling with HSA is possible in loose sand and gravel, loose boulders in
alluvium, clay, silt, shale, and sandstone. HSA drilling is usually limited to unconsolidated materials
and depths of approximately 150 to 200 feet. HSA drill rigs are mobile, relatively inexpensive to
operate, generally cause minimal disturbance to the subsurface materials, and have the additional
advantage of not introducing drilling fluids (e.g., air, mud, or foam) to the formation.

Another advantage of the HSA method is that undisturbed samples are obtained by driving a split-
spoon sampler below the lead auger. Soil samples can usually be easily collected in this manner with
a minimum of tripping sampling tools into and out of the hole.

Moreover, in the HSA drilling method, the well is constructed inside the HSAs as the augers are
gradually removed from the ground. This method decreases the possibility of the borehole collapsing
before the well is installed. HSAs shall have a nominal outside auger-flight diameter of 10 to
12 inches and a minimum inside diameter of 8 inches. Larger inside diameter auger flights are
sometimes available. Well casing diameter is usually limited to 4 inches or less when using the HSA

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
8 of 44

method. The difference between the inner diameter (I.D.) of the auger and the outer diameter (O.D.)
of the well casing shall be at least 4 inches (i.e., a minimum 2-inch annular space) to permit effective
placement of filter pack, bentonite seal, and grout without bridging.

5.4.2	Rotary Bucket Auger

Rotary bucket auger drilling, or bucket auger drilling (BAD), utilizes a large-diameter bucket auger
to excavate earth materials. Excavated material is collected in a cylindrical bucket that has auger-
type cutting blades on the bottom of the bucket. The bucket is attached to the lower end of a kelly bar
that passes through, and is rotated by, a large ring gear that serves as a rotary table.

The kelly bar is square in cross-section and consists of two or more lengths of square steel tubing,
with each successive length of tubing telescoped inside the previous length. This design permits
boring to a depth several times the collapsed length of the kelly bar before having to add a length of
drill rod between the kelly and the bucket. In drilling with the telescoping kelly, the bucket is
typically lifted and dumped without disconnecting, thereby speeding up the process when drilling
deep holes. Depths of 75 to 100 feet are achievable with most telescoping kellys. It is possible to
construct wells more than 250 feet deep by this method, although depths of 50 to 150 feet are more
typical.

The BAD technique is most effective in semi-consolidated or clayey formations that stand open
without caving. Drilling through unconsolidated materials within the saturated zone is difficult, but
not impossible if the hole is kept full of water or mud (see direct rotary methods with foam or mud).
Drilling mud may be necessary, particularly in loose formations consisting of unconsolidated fine- to
medium-grained sands and silts. In the right conditions, a bucket auger bit will remove a cylinder of
material 12 to 24 inches deep with each run. Therefore, samples obtained by the BAD method are
representative of the formation being drilled, unless sloughing or caving of the borehole walls
occurs.

Boreholes drilled with the BAD technique generally range from 18 to 48 inches in diameter. Because
of the large diameter of the borehole drilled with this technique, and the common need to add either
water or mud to maintain the borehole in unconsolidated, near-surface deposits, it is recommended to
use this method only for the installation of surface casing through the first water-bearing unit at a
hazardous waste site.

5.4.3	Direct Rotary with Foam or Mud

Direct rotary drilling (DRD) techniques involve the use of various types of drilling fluids, which
typically include air, foam, and mud. In each of the DRD methods, drilling fluids are circulated
down through the inside of the drilling pipe into the borehole, and then up through the annulus
between the drilling pipe and the borehole wall to carry drill cuttings up to the surface. The drilling
fluids may also be used for stabilizing the borehole wall, which may be especially useful in
unconsolidated, caving formations. In this section, the DRD method and its use with either foam or
mud are discussed.

A variety of bit types may be used with each of these drilling fluids, depending on the type of
formational material encountered; however, typically, the tri-cone or roller bit is used. The drilling
bit is attached directly to a heavy section of drill pipe called a drill collar, which is attached to help
keep the borehole straight. The drill collar is in turn attached to the drill pipe and the kelly.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
9 of 44

General types of drilling fluids available for use with the DRD method include water with clay
additives, water with polymeric additives, water with clay and polymeric additives, and foams
(comprised of air or water, surfactants, and occasionally clays or polymers). The drilling fluid
density may be adjusted during drilling to improve or resume circulation within the borehole, or to
attempt to stabilize the borehole wall. A major problem with the addition of these fluids is that it is
almost impossible to estimate the amount introduced into the formation through the saturated and
unsaturated zones. Additionally, it is also very difficult to estimate the magnitude and duration of the
impact to groundwater quality by the use of these fluids.

The drilling fluids and associated cuttings shall not be allowed to flow over the site unrestricted. A
downhole circulation system, or fluid diversion system shall be used to keep the fluids and cuttings
contained in a reasonable manner, yet still allow the collection of grab samples for lithologic
identification.

While in some geologic situations DRD may be the most efficient method of drilling a borehole,
potential problems associated with the drilling fluids usually make DRD a last-resort drilling
technique for environmental purposes; one that should be avoided whenever possible.

Potential Problems of DRD with Foam or Mud

The chemistry of the drilling fluid could adversely affect the chemistry of groundwater
samples, soil samples, or the efficiency of the well (when using mud).

Bentonite mud reduces the effective porosity of the formation around the well, thereby
compromising the estimates of well recovery. Bentonite may also affect groundwater pH.
Additives to adjust viscosity and density may introduce contaminants to the system or force
irrecoverable quantities of mud into the formation.

Some organic polymers and compounds provide an environment for bacterial growth, which
in turn, reduces the reliability of sampling results.

Uncontained drilling foam and/or mud may create unsafe working conditions at the surface
around the rig.

DRD should only be utilized as a last resort.

The hydrogeologist should ensure that the fluids used will not affect the chemistry of the soil
samples and groundwater samples. One possibility is to collect samples of the drilling fluid
for laboratory analysis.

The hydrogeologist shall keep track of the amount of water and fluids introduced to the
borehole in order to purge this quantity during well development.

Provisions to contain drilling mud and foam shall be discussed in the drilling contractor
scope of work.

5.4.4 Air Rotary and Air Rotary with Casing Hammer

Air rotary drilling (ARD) and air rotary with casing hammer (ARCH) force air down the drill pipe
and back up the borehole and remove drill cuttings in the same manner as DRD with foam or mud.
Without a casing hammer, the use of ARD techniques is best suited to hard-rock formations where

Solutions

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
10 of 44

the borehole will stand open on its own and circulation loss is not a major concern. ARCH is most
useful in unconsolidated sediments of all types due to the use of a hardened steel casing that is driven
behind the bit with a pneumatic casing hammer to keep the hole open. A combination of these two
drilling techniques is very useful where unconsolidated overburden overlies consolidated rock. In
this case, the casing hammer attachment would be used to set the surface casing at the top of the
consolidated formation while continuing with ARD. As a well is being installed or the hole is being
abandoned, the casing can be retrieved for use on another hole, or left in place to serve as surface
casing.

Air from the compressor shall be filtered to ensure that oil or hydraulic fluid is not introduced into
the soils and/or groundwater system to be monitored. In addition, foam or hydrocarbon-based
lubricating joint compounds for the drill rods shall not be used with any rotary drilling method due to
the potential for introduction of contaminants into the native materials and/or groundwater.
Teflon-based joint lubricating compounds that are typically mixed with vegetable oil are available
for this purpose.

Potential Problems of ARD and ARCH

In the case of sampling with a split-spoon sampler to collect soil samples for laboratory
analysis, the high-pressure air from inside the drill pipe can cause volatilization of
contaminants from the soils beneath the bit in unconsolidated sediments. If installing deep
wells or boreholes, this problem may not be avoidable.

Fine-grained saturated materials that may cause surging and heaving problems are common
in many coastal areas. Heaving sediments may cause problems during sampling and well
installation when drilling with ARD.

Rocks and other drill cuttings may be ejected from the borehole at high velocities, creating a
secondary hazard around the rig.

ARD and ARCH should not be used for soil sampling in shallow, unconsolidated situations
where a HSA rig could be used as effectively.

One method to compensate for heaving and surging aquifer materials is to over drill the
borehole by 5 or 10 feet to provide space for heaving sediments to fill in while well
completion is being performed.

Another method to control heaving sands is to add clean water to a level above the water
table to create a downward pressure on the heaving materials. This additional volume of
water should also be extracted during well development.

Drill rigs shall be equipped with cyclones or equivalent devices designed to contain
formation projectiles.

5.4.5 Dual Tube Casing Hammer with Reverse Air Circulation

Dual tube casing hammer with reverse air circulation (DTCH) is useful in unconsolidated sediments,
but is most effective as a method for drilling through thick sequences of materials, such as coarse-
grained sands and gravels. The DTCH system operates by simultaneously driving a pair of heavy
gauge steel pipes into the ground while using high pressure reverse air circulation to blow air down

Solutions

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
11 of 44

the annulus of the two pipes and bring air and unconsolidated lithologic materials out through the
inside of the inner pipe. The method does not employ a typical bit in that the formational materials
are not ground up, sliced, nor cut into pieces. Instead, the bit consists of a special shoe that is used to
funnel materials either into, or away from, the inner pipe, depending on whether the formational
material is fine- or coarse-grained, respectively.

Typically, the method can drill through 200 feet of gravel in a day with relative ease. The inside
diameter of the inner pipe is about 6 inches, with the borehole diameter being about 10 inches.
Cobbles with long axes of up to 6 inches come up through the inner pipe easily. Larger conglomerate
clasts must be either pushed aside or broken up using the pneumatic hammer to drive the heavy shoe
down onto the clast.

Conversely, the method works poorly in clay-rich materials. The shoe acts as a large cookie cutter,
forcing a plug of clay into the inner pipe, which then must be forced to the surface and physically
removed from the diverter/shoe assembly with the hammer. This method should probably be avoided
where large thicknesses of clay are expected to be encountered in the subsurface.

Typically, the DTCH method can drill to approximately 200 feet with standard equipment. Deeper
holes will likely require a larger air volume for circulation via an additional compressor hooked up to
the drilling rig. Additionally, a variation of the DTCH called "triple tube" can be used to install
larger-diameter wells to depths of about 200 feet depending upon the site. This method can also be
used to supply a temporary surface casing to avoid cross-contamination of deeper zones while
extending the boring to greater depths.

Potential Problems of DTCH

In the case of soil sampling with a split-spoon sampler to collect samples for laboratory
analysis, the high-pressure air from inside the drill pipe can cause volatilization of
contaminants from the soils beneath the bit in unconsolidated sediments. If installing deep
wells or boreholes, this problem may not be avoidable.

DTCH should not be used for sampling soil in shallow, unconsolidated situations where a
HSA rig could be used as effectively.

5.5 Monitoring Well Design Procedures

The designs of typical groundwater monitoring wells are depicted in Figure I-C-l-1 and
Figure I-C-l-2. A discussion of the design of the individual components of a typical monitoring well
is given in the following subsections.

5.5.1 Pre-installation Design Drawing

Develop a pre-installation design drawing after the borehole for the well has been completed and
well-specific lithologic and hydrologic information are available. The pre-design drawing shall
identify the anticipated depth of the well, the locations of the top and bottom of the screened interval,
the anticipated top of the filter pack, the anticipated top of the bentonite seal, and the locations of
centralizers (if applicable). In addition, calculate the volumes of sand, bentonite, and grout

Solutions

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
12 of 44

anticipated to be placed in the annular space of the well. Maintain the drawing as documentation of
the well design.

5.5.2 Casing Selection

The cased section of a monitoring well is a pipe without slots or openings, which is installed to
prevent the well from directly accessing formations above the screened interval. The casing isolates
the screened interval.

The selection of appropriate casing materials must take into account several site-specific factors,
such as: (1) geology, (2) geochemistry, (3) well depth, (4) size and type of equipment to be used in
the well, and (5) the types and concentrations of suspected contaminants. In addition, consider
several other logistical factors, including drilling method, cost, and availability.

Typical casing materials comprise polyvinyl chloride (PVC), chlorinated PVC, fiberglass reinforced
plastic, Teflon, galvanized steel, carbon steel, Type 304 stainless steel, and
Type 316 stainless steel. Casing materials must be compatible with the environment into which they
will be placed. Metallic casings are most subject to corrosion, while thermoplastic casings are most
subject to chemical degradation. Some thermoplastic materials are susceptible to sorption and
desorption of chemicals. The extent to which these processes occur is related to water quality, the
concentration of contaminants, and the type of casing materials. Choose casing material with
knowledge of the existing or anticipated groundwater chemistry. If non-aqueous phase liquids (light
non-aqueous-phase liquid or DNAPL) are potentially present at a site, careful consideration of the
concentrations and types of chemicals that may come into contact with the casing must be made to
insure the casing will not degrade over time. Table I-C-l-2 presents the relative compatibilities of
some typical casing materials.

Table l-C-1-2: Relative Chemical Compatibility of Rigid Well-Casing Material



PVCa1

Galvanized
Steel

Carbon
Steel

Low-Carbon
Steel

Stainless b
Steel 304

Stainless b
Steel 316

Teflon 0

Buffered weak acid

100

56

51

59

97

100

100

Weak acid

98

59

43

47

96

100

100

Mineral acid/high
solids

100

48

57

60

80

82

100

Aqueous/organic
mixtures

64

69

73

73

98

100

100

Percent overall ratingd

91

58

56

59

93

96

100

a PVC casing shall not be installed in a groundwater environment containing chlorinated solvent or other destructive
contaminants where the concentration of organics is greater than 1 part per million, and where the desired detection limit is
less than 25 part per billion.

b Type 316 stainless steel screen and/or casing shall be used rather than type 304 when conditions are unknown and the
lifespan of the monitoring well is to be greater than 5 years, or where the pH (indicates the hydrogen ion concentration -
acidity or basicity) is less than 4.5, or where chloride concentration is greater than 1,000 part per million.

0 Trademark of E.I. DuPont de Nemours

d Overall rating based on scale of 0 to 100 with 0 being the least compatible and 100 being the most compatible.

Besides chemical compatibility, a second consideration for specification of casing materials is the
depth of the monitoring well. Well installations greater than 150 feet deep require casing materials of
greater structural strength. In the case of PVC casing, Schedule 80 PVC rather than Schedule 40 may
be required to prevent over-stressing of the casing couplings. The build-up of heat during grout setup
might adversely affect some thermo-plastic materials.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
13 of 44

Regardless of the type of casing materials, use only flush-threaded couplings. Flush-threaded
couplings ensure that no screws, mechanical adapters, glues, or solvents are necessary to join
individual sections. Steel conductor casing shall be welded at the joints, and the joint shall be at least
as thick as the thickness of the casing wall. The weld shall be fully penetrating and shall meet the
standards of the American Welding Society. Outside steel collars may be used to increase the
strength of the welded joint. Do not use Teflon tape on PVC or stainless steel casing joints because it
reduces the tensile strength of the joints.

The selection of an appropriate casing diameter is also important. The I.D. shall be 4 inches or
greater to allow better access to the well and more rigorous well development than is commonly
possible with smaller-diameter wells. Wells with casing smaller than 4-inch I.D. shall only be
installed with the approval of the QA Manager or Technical Director. Wells greater than 150 feet in
depth may require diameters larger than 4 inches to ensure that development and sampling
equipment can be moved easily through the well. In addition, wells designed for groundwater
extraction shall have a casing diameter large enough to accommodate a pump capable of achieving
the appropriate pumping rate. The borehole in which the well is to be installed shall be a minimum of
4 inches larger in diameter than the O.D. of the well casing.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page;

l-C-1
May 2015
14 of 44

NOT TO SCALE

Figure l-C-1-1: General Cross Section of Monitoring Well, Unconfined Water Bearing Zone

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
15 of 44

GROUND SURFACE

WATER TABLE

sz.

LOCKING WELL CAP
WELL HEAD COVER (TRAFFIC BOX)

BENTONITE/CEMENT GROUT

BENTONITE (3 TO 5 FEET
ABOVE FILTER PACK)

FILTER PACK (AT LEAST 2
FEET ABOVE SCREEN)

SCREEN INTERVAL

BOTTOM. CAP

NOT TO SCALE

Figure l-C-1-2: General Cross Section of Monitoring Well, Confined Water Bearing Zone

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
16 of 44

5.5.3 Well Screen Selection

The screened section of the monitoring well allows groundwater to flow freely into the well, while
retarding movement of fine-grained lithologic materials into the well. When designing a well screen,
consider important factors, such as type of well screen material, length of the screened section,
location of the screened section, the intake opening (slot) size, the type of intake opening, and size of
filter pack to be utilized.

Five factors directly affect the performance of the monitoring well and are evaluated in the selection
of an appropriate screen: (1) chemical resistance/interference, (2) screen length, (3) screen
placement, (4) intended use of well (e.g., long-term groundwater extracted); and (5) intake opening
size.

Selection of a screen material that provides chemical resistance and minimizes interference follows
the same basic procedures as the selection of an appropriate casing material (see Table I-C-l-2).
Some typical screen materials consist of PVC, Teflon, Type 304 stainless steel, and Type 316
stainless steel. Again, use only flush-threaded couplings. Screen sections constructed of different
metals in the same well may cause electrochemical reactions that could rapidly degrade the casing or
screen; therefore, do not use this type of composite well construction. In addition, construct wells
intended for long-term groundwater extraction with well screen rather than slotted casing for
facilitating redevelopment.

Selection of the screen length depends on its primary use(s). Most monitoring wells function as both
groundwater sampling points and piezometers. Shorter-screened sections provide more specific data
on vertically distributed contaminants, hydraulic head, and flow, and are generally preferred to
longer-screened lengths. Saturated sections in groundwater monitoring wells shall be limited to
between 5 and 10 feet in length; however, longer intervals may be justified in certain circumstances
with approval of the QA Manager or Technical Director.

Placement of the screened interval within a groundwater monitoring well depends primarily upon
two factors: the discrete interval and the type of contaminants to be monitored. The location of the
discrete interval to be monitored will dictate the location of the screened interval within a monitoring
well; however, also consider the characteristics of the contaminants to be monitored (i.e., light,
non-aqueous phase liquid; dense, non-aqueous phase liquid) when choosing placement of the
screened interval.

An additional consideration in the design of the screened section of the well is the hydraulic
characteristics of the water-bearing zone that is to be monitored (i.e., confined or unconfined). If an
unconfined zone is being monitored for contaminants that are less dense than water (e.g., gasoline,
diesel, waste oil), place 3 to 5 feet of screened interval above the highest level of the water table to
allow for evaluation of fluctuations in water level and to ensure that contaminant phases less dense
than water can be observed. Conversely, if an unconfined zone is being monitored for contaminants
that are denser than water (e.g., chlorinated solvents), place approximately 5 feet of screened interval
(maximum) just above the confining unit at the base of the water-bearing zone to facilitate detection
of the dense-phase contaminants. In the case of a confined water-bearing zone, use a maximum-
screened interval of approximately 5 feet.

Selection of an appropriate intake opening size is critical to the performance of the monitoring well
and to the integrity of groundwater samples obtained from the well. The size of the intake openings

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
17 of 44

can only be determined following the selection of an appropriate filter pack, which itself is selected
based upon the grain-size of the formation. An intake size is generally designed to hold back
between 85 to 100 percent of the filter pack material. Figure I-C-l-3 can be used to select
appropriate intake opening sizes. The screen slots shall be factory-made (or formed).

5.5.4	Filter Pack Design

Filter pack material shall be clean and chemically stable within the monitoring well environment to
minimize addition to, or sorption from, the groundwater. Filter pack shall meet the following
minimum specifications:

Filter pack material shall be at least 95 percent silica, consisting of hard, durable grains that
have been washed until free of dust and contamination, and graded.

Filter pack material shall not be angular and non-uniform such that it will bridge in the
annular space, leaving a void or poorly packed materials that can consolidate or settle after
construction.

Select filter pack to meet the grading specification determined from sieve analysis of the
geologic formation to be screened, if available.

Filter pack material shall be commercially packaged in bags that prevent the entrance of
contaminants, and allow proper handling, delivery, and storage at the monitoring well site.
Do not use material delivered in broken bags for monitoring well construction.

In investigations where there are limited data on site conditions prior to monitoring well installation,
select the filter pack size prior to field activities based on available lithologic data. Use finer filter
pack sizes if fine-grained formations are anticipated to be present, and use coarser-grained filter
packs in coarser lithologies and consolidated formations.

In investigations where sieve analysis data exist for a site prior to field activities, base selection of a
proper filter pack upon the grain size of the formation materials to be monitored. Use the sieve data
for the finest lithology identified in the interval to be monitored for establishing filter pack size. The
U.S. Environmental Protection Agency recommends that filter pack grain size be selected by
multiplying the 70 percent retained grain size of the formation materials by a factor between 4 and 6.
Use a factor of 4 if the formation materials are fine-grained and uniform, and use a factor of 6 if the
formation materials are coarse-grained and non-uniform. In any case, the actual filter pack used
should fall within the area defined by these two curves. An example of this technique is presented in
Figure I-C-l-4.

5.5.5	Annular Seal

The annular seal is placed directly above the filter pack in the annulus between the borehole and the
well casing. The annular space must be sealed to prevent the migration of water and contaminants
through the annulus. The annular seal is also intended to hydraulically and chemically isolate
discrete water-bearing zones.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
18 of 44

y.s st^-icwo ;,tvr uuuecp;

100 7 0 5040 30 20 16	12	8

103

Figure l-C-1 -3: Selecting Well Intake Slot Size Based on Filter Pack Grain Size

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
19 of 44

<.
UJ

5

ZD

5
5
O

U.S. STANDARD SIEVE NUMBERS
100 70 50 40 30 20 16	12

100
90
80
70
60

O 50

CK

LU
CL
UJ
:>

40
30
20
10
0

Filter Pock Ratio = 6
Uniformity Coefficient

Fitter Pack Ratio = 4 (_•
Uniformity Coefficient = 2.2

Uniformity Coefficient = 2.5
Filter Pack Ratio = 4 to 6
D. =0.014 inch

Range for

Filter Pock Gradation

Formation
Gradation

10 20 30 40 50 60 70 80 90 100 110 120

SLOT OPENING AND GRAIN SIZE, IN THOUSANDTHS OF AN INCH

Figure l-C-1-4: Filter Pack Design Criteria

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
20 of 44

Typically, annular seals consist of two discrete sections. The first section, known as the bentonite
seal, consists of a pure sodium bentonite seal. To be effective, the bentonite seal should be emplaced
directly over the top of the filter pack and extend approximately 3 to 5 feet (no less than 3 feet thick).
Typical materials for the seal consist of granular sodium bentonite, or sodium bentonite pellets or
chips.

The second section of the annular seal typically contains grout slurry, which completely fills the
remaining annular space from the bentonite seal to just below the ground surface. Grout consists of
either sodium bentonite and Portland cement slurry or neat cement slurry. Give special consideration
to the selection of annular seal material for wells installed in coastal areas where groundwater may
contain elevated concentrations of sulfates. In this situation, use a sulfate resistant grout to prolong
the usefulness of the well.

5.5.6 Surface Completion

The surface of the well shall be completed using either an above-grade (monument) style, or a
flush-to-grade (traffic box) style. In either case, the protection of the wellhead at land surface is
accomplished by means of a surface seal of concrete and a metal completion box surrounding the
well casing. The surface seal serves to prevent infiltration of surface water and unauthorized entry,
and where necessary, to provide protection from vehicular traffic.

5.6 Monitoring Well Installation Techniques

The following general procedures describe the installation of groundwater monitoring wells.

5.6.1	General Casing and Screen Installation Techniques

Following completion of the borehole, the FM or designate will first measure the total depth of the
hole to ensure that the desired depth has been attained. The lengths of casing and screen shall also be
measured. These measurements shall be made with an accuracy of 0.01 feet using either a fiberglass
or steel tape measure.

Installation of the casing and screen is normally accomplished by emplacing them into the well as an
integral unit. Prior to installation, decontaminate individual lengths of the well casing and screen
according to Procedure I-F, Equipment Decontamination, unless the casing and screen were certified
by the manufacturer to have been properly pre-cleaned at the factory and sealed in plastic. Following
decontamination, inspect each length to ensure that damaged or otherwise unsuitable sections are not
used.

To ensure even distribution of filter pack, bentonite seal, and grout materials around the well within
the borehole, suspend the casing and screen with a threaded hoisting plug and do not allow them to
rest on the bottom of the boring unless the installation is less than 30 feet deep.

5.6.2	Centralizers

Install centralizers at the top and bottom of screened sections when using the air or mud rotary
techniques for well installation. Also place centralizers at 20-to 40-foot intervals on blank casing; the
FM will determine the spacing according to the depth of the well. Align the centralizers from top to
bottom of the casing so that they do not interfere with the insertion and removal of the tremie pipe. All
devices used to affix centralizers to the casing shall not puncture the casing or contaminate the
groundwater with which they come in contact. Centralizers shall be constructed of stainless steel.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
21 of 44

5.6.3 Filter Pack Installation

Prior to the addition of any filter pack material, cover the top of the well casing to prevent filter pack
material from entering it.

The filter pack is usually installed through HSAs, conductor casing, or a tremie pipe depending on
the drilling technique used; however, if the depth to the bottom of the screened interval is less than
10 feet, and lithologic materials are sufficiently consolidated to preclude the possibility of hole
collapse, the filter pack may be poured into the annular space of the well from the ground surface.
This procedure applies to any drilling method.

During installation, measure the level of the top of the filter pack periodically to ensure that no
bridging has occurred, and to determine the depth to the top of the filter pack. Be sure that the filter
pack encloses the entire length of the screened section. For wells less than 100 feet in total depth, the
filter pack shall generally extend to 2 feet above the top of the screened section of the well. For wells
greater than 100 feet in total depth, an additional 1 foot of filter pack may be emplaced above the
screen for each 100 feet of well depth.

An alternative to conventional monitoring well construction and installation is through the use of
small diameter pre-fabricated monitoring wells, commonly referred to as "pre-pack" wells. Pre-pack
wells typically consist of a well screen (slotted PVC) surrounded by sand (filter-pack) held in place
by a stainless steel or polyethylene mesh. The pre-pack well assembly is commonly used in
conjunction with direct-push drilling methodologies, which allows a relatively quick installation of
these small diameter wells. Having the filter pack around the slotted PVC before the well screen is
installed ensures that the filter pack is located directly around the well screen and minimizes the
effort required for the filter pack installation.

The filter pack is normally an inert (e.g., siliceous) granular material that has a grain-size distribution
chosen to retain formation materials. A sleeved screen consists of a slotted pipe base over which a
sleeve of stainless steel mesh filled with selected filter media is installed. Pre-packed or sleeved
screens may be used for any formation conditions, but they are most often used where heaving,
running or blowing sands make placement of conventional well screens and filter packs difficult, or
where predominantly fine-grained formation materials are encountered (ASTM 2010). During
installation, the boring is advanced using hollow drive rods with an expendable drive point. Upon
reaching the desired monitoring well installation depth, the entire well assembly (i.e., pre-pack well)
is lowered to the desired depth within the hollow drive rods. At the desired depth, the hollow drive
rods are retracted to a point above the screen. At this step a barrier is placed directly above the screen
to prevent grout or material from entering the screened interval as the hollow drive rods are extracted
from the boring. This barrier can be created either by natural formation collapse (occurring during
the initial rod retraction), by gravity installation of fine-grade sand through the rod annulus, or as
part of the pre-pack monitoring well components (e.g. expanding foam bridge). With the barrier in
place, granular bentonite or bentonite slurry is then installed in the annulus to form a well seal. When
installing pre-pack screens additional sand must be used to fill in the annular space between the
pre-pack and the edge of the borehole. Furthermore, filter sand should be installed to at least 2 feet
above the top of the pre-packed well screen.

Vendors offer pre-pack monitoring well components with varying outer diameters, which is typically
based on the inner diameter of the hollow drill rods. These types of wells may be sampled by several

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
22 of 44

methods including peristaltic pump, mini-bailer, or bladder pump to yield data of similar quality to
that of conventional monitoring wells.

Following the installation of the filter pack, a surge block or large bailer shall be placed into and
removed from the casing for approximately 10 minutes to set and compact the filter pack and to
begin well development. Then, check the level of the filter pack again. Add more filter pack material
according to the procedures described above if any settling of the filter pack has occurred. After
emplacement, note the volume of filter pack material placed in the well, record it in the well
completion record (Figure I-C-l-5), and compare it to the calculated volume of filter pack that was
expected to have been used.

5.6.4 Annular Seal Installation

The sodium bentonite seal shall have a minimum thickness of 3 feet. Generally, to be effective the
bentonite seal should extend above the filter pack approximately 3 to 5 feet. It may be constructed of
powdered, granular, or pelletized bentonite, and may be emplaced as a dry solid, powder, or slurry.
Use only sodium bentonite manufactured specifically for use in the drilling and construction of water
wells. Typically, granular or pelletized bentonite is emplaced dry. Powdered bentonite is usually
mixed with potable water to produce a slurry. Depending on the type of installation method, the
bentonite may be emplaced through the HSAs, conductor casing, or tremie pipe.

In dry form, place the bentonite directly on the top of the filter pack. After emplacing each
1-foot-thick layer of dry bentonite in the well, add approximately 5 gallons of water of known
chemical quality to hydrate the bentonite. Allow a minimum of 15 minutes for hydration of the
bentonite seal once it is completely installed.

When emplacing the bentonite in slurry form, take care to ensure that the bentonite is thoroughly
mixed, with no visible lumps to ensure the proper consistency. Then place a 1-foot layer of
fine-grained silica sand over the top of the filter pack. This fine-grained sand layer will prevent
infiltration of the filter pack by the bentonite slurry.

Emplace the remaining annular seal following the installation of the bentonite seal. The annular seal
shall be a slurry consisting of 7 to 9 gallons of water per 94-pound bag of Portland cement Type I or
II and a minimum of 3 to 5 percent bentonite (1/4 to 1/2 bags of bentonite powder per five bags of
Portland cement). The slurry may be emplaced through a HSA, conductor casing, or tremie pipe,
depending on the method of installation. Thoroughly mix the grout to ensure the proper consistency
with no visible lumps of dehydrated powder. The rates at which the augers or pipe are withdrawn
and the slurry added will be such that the level of the grout within the well annulus is just below the
lowermost auger or pipe.

If a tremie pipe is used, emplace the annular grout seal by pumping through a pipe with a minimum
1-inch I.D., in one continuous pour, from the top of the transition seal to the ground surface. Place
the bottom of the tremie pipe about 5 to 10 feet above the transition seal, depending on the stability
of the hole and impact velocity of the grout.

A tremie pipe is not required for annular seals less than 10 feet from the ground surface to the top of
the transition seal or for grouting within dual wall drill strings or HSAs. Measure the volume of
grout seal material placed in the well, record it in the well construction log, and compare it with the

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
23 of 44

calculated volume. The slurry shall extend from the top of the bentonite seal to a depth of
approximately 2 feet below ground surface (bgs).

5.6.5	Annular Seal "Set Time" and Setting

Let the annular grout seal set at least 12 hours before disturbing the casing or well so that separations
or breaks do not occur between the seal and the casing, or between the seal and the borehole.
Development of the well is prohibited until the grout seal has set. Likewise, the concrete slab, traffic
box, and/or casing riser of the surface completion shall not be poured and constructed until the grout
seal has set. Top off any settlement of the grout seal as soon as possible after it sets. Record all
pertinent data on the well construction log.

5.6.6	Surface Completion

The surface of a groundwater monitoring well shall be either an above-ground completion or as a
flush-to-ground completion. Regardless of the method, each monitoring well shall have, at a minimum,
a casing cap, concrete slab and annular seal, and a locking protective casing or locking vault. Although
wellheads vary in size, effort should be made to use a consistent size wellhead or similar completion
per site.

In an above-ground completion, the protective casing or monument is installed around the top of the
well casing within a cement surface seal. A 2-foot-long by 2-foot-wide cement pad with a minimum
thickness of 3 inches is constructed around the protective casing. Type 1 Portland cement, which
meets the requirements of CLASS A standards, is used for the surface seal. Inspect the monument
prior to installation to ensure that no oils, coatings, or chemicals are present. Once installed, maintain
the monument in a plumb position with 2 to 3 inches of clearance between the top of the well casing
and the lid of the monument. The monument shall extend at least 18 inches above grade and at least
12 inches below grade. Construct a minimum of three concrete-filled posts around the well to protect
it from vehicular damage.

Inside the monument, cut or scribe two permanent survey marks, approximately 0.25 inches apart,
into the top of the well casing, and also permanently mark the well with its identification number.
Permanent marks may include painting, marking, or engraving on the protective casing or surface
completion. An alternate option may be to attach a non-corroding, imprinted metal tag to part of the
well. Cover the top of the well casing with a slip cap or locking cap to prevent debris from entering
the well. Fit the monument with a casehardened lock to prevent unauthorized entry.

In a flush-to-ground completion, the protective casing or traffic box is installed around the top of the
well casing, which has been cut off slightly below grade. The traffic box has a lid that is held firmly
in place by bolts and has a flexible O-ring or rubber gasket to prevent water from entering the box.
Whenever possible, wells with flush completions should not be placed in low spots where surface
water can accumulate. If this is unavoidable, consider an aboveground completion. The traffic box is
set within a cement surface seal slightly above grade to deflect surface water flow away from the
well. The surface seal must form an apron at ground surface that is at least 2 feet wide and 4 inches
thick. The concrete apron must slope away from the well (a minimum of 1 percent) to prevent
surface water leakage into the well head (DOH 2009). An effort should be made to standardize the
appearance of the well completions at a particular site. Type 1 Portland cement, which meets the
requirements of CLASS A standard, is used for the surface seal. Where monitoring well protection
must be installed flush with the ground, an internal cap should be fitted on top of the riser within the

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
24 of 44

manhole or vault. This cap should be leak-proof so that if the vault or manhole fills with water, the
water will not enter the well casing. The cap should also be able to lock to prevent unwanted access
or tampering with the well. Ideally, the manhole cover cap should also be leak-proof (ASTM 2010).
Inspect the traffic box prior to installation to ensure that no oils, coatings, or chemicals are present.
Once installed, maintain the traffic box in a level position that leaves 2 to 3 inches of clearance
between the top of the well casing and the lid of the traffic box. Regular maintenance may be
necessary to maintain the integrity of the seals and pads protecting the wells.

Cut two permanent survey marks into the top of the well casing, approximately 0.25 inches apart,
and also permanently mark the well with its identification number. Cover the top of the well casing
with a lockable cap to prevent debris from entering the well. Also fit the lockable cap with a
casehardened lock to prevent unauthorized entry.

In areas where there is a high probability of damaging the well (high traffic, heavy equipment, poor
visibility), it may be necessary to enhance the normal protection of the monitoring well through the
use of posts, markers, signs, or other means. The level of protection should meet the damage threat
posed by the location of the well (ASTM 2010).

5.6.7 Installation of Surface Casing

The use of surface casing may be required to minimize the potential for cross-contamination of
different hydrogeologic zones within the subsurface of a site. The depth of placement of the surface
casing shall be based on site-specific geologic knowledge obtained from lithologic samples collected
in situ during the drilling of the well boring.

If a surface casing is to be installed permanently along with the well, grout it in place. The borehole
shall be of sufficient diameter that a tremie or grout pipe can be easily placed between the borehole
wall and the outside of the surface casing. After the desired placement depth is reached and the
drilling tools are removed from the borehole, lower the casing into the borehole and center it. The
bottom of the surface casing may be plugged or driven into the sediment at the base of the borehole
to keep grout from entering the casing, if necessary.

Install grout through the tremie pipe and pump it from the bottom of the casing to ground surface. As
the grout is being placed, raise the tremie pipe slowly to avoid excessive backpressure and potential
clogging of the tremie pipe. After the grout has been allowed to set for at least 24 hours, drilling and
subsequent well installation can continue. The required time for grout to set before drilling can
continue depends on the volume of grout emplaced; the more grout used, the longer the delay time.

-------
NAVFAC Pacific ER Program	Procedure Number;	l-C-1

Monitoring Well Installation and Abandonment	Revision Date:	May 2015

Page:	25 of 44

JOB NO.:
CLIENT:

WELL MO.

HYDROGEOLOGIST:

WELL LOCATION:

DRILLER:
DATE/TIME:

DETAILS OF CONSTRUCTION
Date

Completed

GROUND SURFACE

Borehole Diameter (in.)

Type and Size of
Casing (in.)

Type and Size
of Screen (in.)

Screen Perforation
Diameter (in.)

Screen Length (ft.)

Centralizer Depths (ft.)
Completion Technique
1. Type of Filter Pack and
Racement Method

2. Type of Be ntcnite and
Placement Method

3. Type of Grout Mixture and
Ra cement Method

Description of Potential Problems
With Well:

Development Technique

I I

Well Head Elevation

Ground Surface Elev.

Well Head Completion Method

Drilling Method/Rig Type

Surface Casing:	Type

Diameter
Length

MATERIALS
Cement (sks.)

Filter Pack Material
(It.5!

Casing Material (ft.)
Benton ite (ft.3)

Top of Be ntonite
Seat

Top of Filter Pack
Top of Screen

Bottom of Screen	ft.

Bottom of Hole	ft.

NOTE: ALL DEPTHS ARE REFERENCED
TO GROUND SURFACE

Figure l-C-1-5: Well Completion Record

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
26 of 44

5.6.8	Shallow Well Completion

Due to the occurrence of shallow groundwater in some areas, there are instances when the top of the
screened interval must be placed at a depth so shallow that it is impossible to install the well using
the typical design for annular materials (i.e., 2 feet above the screen for filter pack followed by a
3-foot thickness of bentonite seal). In cases where the top of the screen must be placed between
4 and 6 feet bgs, use the following design alteration:

Place the filter pack 1 foot above the top of the screened interval.

Place a minimum of 3 feet of bentonite seal above the filter pack.

Fill the remainder of annular space with a 3 percent to 5 percent bentonite-cement grout.

In no case shall the top of the screen be brought higher than 4 feet bgs because it is difficult to install
a reliable annular seal at these shallow depths.

5.6.9	Method-specific Well Installation Techniques

The following sections describe well installation techniques for groundwater monitoring at
hazardous waste sites. Sections on troubleshooting common problems encountered when using each
technique and potential solutions to the problems are included.

5.6.9.1 HSA

General methods of well installation using the HSA technique are listed below:

Complete a pre-installation design drawing in accordance with Section 5.4.1.

Prior to well installation, properly decontaminate and measure the well screen, cap, and
casing to ensure accurate placement of well casing and screen. Mark the well casing near the
ground surface to signal to the drillers where the casing should be placed.

Remember that wells are constructed within the augers as the augers are removed from the
ground.

The diameter of the well casing constructed within an HSA is limited to 4 inches. Note: The
difference between the I.D. of the HSA and O.D. of the well casing must be at least 4 inches
to permit effective placement of filter pack, bentonite seal, and grout.

Remove the inner rod and hammer quickly, measure the depth of the borehole, and place the
well screen and casing quickly into the auger to the desired depth. Note: the well screen and
casing shall be suspended in hole by the use of a hoisting bail in order to ensure proper depth
and plumb construction. This may not be necessary for wells less than 30 feet in depth.

Prior to adding filter pack, cover the top of the well casing to prevent filter pack material
from entering it.

The HSA acts as tremie pipe for placement of filter pack, bentonite, and grout.

Slowly pour filter pack between the inside of the auger and the outside of the well casing.

While the filter pack material is being poured, incrementally withdraw the auger. The rate of
auger withdrawal and filter pack placement shall allow for the top of the filter pack level to
be just below the lead auger. In general, the augers should be withdrawn in increments of

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
27 of 44

2 to 3 feet. Note: The level of the top of the filter pack shall be constantly tagged with a
measuring tape during emplacement of the filter pack.

Surge the well to consolidate the filter pack; add more if settlement occurs.

Emplace bentonite pellets or chips through the HSA. Tag the level of the bentonite
periodically to ensure accurate placement. For each foot of bentonite seal installed in an
unsaturated completion, pour 5 gallons of water of known chemical quality into the well to
hydrate the bentonite. If the bentonite seal is less than 10 feet bgs and the borehole is stable,
the bentonite may be emplaced directly from the top of the borehole rather than through the

After allowing 15 minutes for the bentonite seal to hydrate, emplace a grout seal through the
HSA from the top of the bentonite seal to within 2 feet of ground surface. The grout shall be
emplaced from bottom to top in one continuous pour. If the top of the bentonite seal is less
than 10 feet bgs and the borehole is not subject to collapse, the grout may be emplaced
directly from the top of the borehole. If the top of the bentonite seal is greater than 10 feet
bgs, a tremie tube shall be used to emplace the grout. The composition of the grout is
detailed in Section 5.4.5.

Construct an above- or below-ground wellhead.

Potential Problems and Solutions

Bridging Filter Pack or Bentonite Seal

Bridging filter pack or bentonite can create unwanted void spaces or lock the well casing within the
HSA.

Avoidance of Locked Well Casing

Carefully tag the filter pack level and keep it just below the lead auger while the auger is
inched up and sand is slowly added.

Use an auger with a larger I.D.

Use filter pack materials with a larger grain size.

Add water of known chemical quality while pouring the sand filter pack. Try this only in
cases where the filter pack is very fine.

Solutions for Unlocking Well Casing from Augers

Gently hold the casing in place while lifting and twisting the auger (do not force).

Insert the surge block into the casing and gently surge the water column if bridge is below
water table.

Add water between the well and auger if the sand bridge is above the water table.

Attach an air compressor to a tremie pipe, and then gently blow the bridge away.

Completely remove the casing and screen, and reinstall the well.

HSA.

Never drive the casing out of the auger with a hammer because this will break the casing.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
28 of 44

Heaving, Surging Materials

Fine-grained saturated materials that might cause surging problems are common in coastal areas.
Heaving sediments might cause problems when drilling with HSA.

Solutions for Heaving Sediments

Over-drill the borehole by 5 or 10 feet to provide space for heaving sediments to fill in while
well installation begins. Begin placement of filter pack as soon possible. Add it quickly until
over-drilled space is filled.

Add clean water to a level above the water table to create a downward pressure on the
heaving materials. The volume of water added shall be recorded on the well installation log
and extracted during well development.

Drill an initial pilot borehole and sample with a 6-inch-diameter auger. The 6-inch auger
may be fitted with plastic or metal core catcher on the lead auger, which will allow for soil
sampling and prevent sediments from entering augers. After the total sampling depth is
reached, the 6-inch auger is removed and 10-inch-diameter augers are substituted to ream
out the borehole. Fit the lead auger with a tapered stainless steel plug. At a depth below the
desired total depth of the well, use the sampling hammer and center rod to knock out the
stainless steel plug. Then complete well installation.

5.6.9.2 Direct Rotary with Foam or Mud

General well installation techniques using direct rotary with foam or mud are listed below:

Complete a pre-installation design drawing in accordance with Section 5.4.1.

Prior to well installation, measure the well screen, cap, and casing to ensure accurate
placement of well casing and screen. Place mark on the portion of the well casing near
ground surface to identify to the drillers where the casing should be placed. Place
centralizers on the well casing and screen as discussed in Section 5.5.2.

With DRD techniques, wells are constructed in the borehole after the bit and drill pipe are
removed from the hole. For mud rotary drilling, first thin the mud sufficiently prior to
removing the bit and drill pipe from the hole. Thinning the mud allows faster and more
accurate placement of the annular materials within the borehole, which balances the density
of the borehole fluids so they more closely match the density of the fluids used to install the
filter pack and bentonite seal. It also reduces the potential for annular materials to be washed
out of the borehole through the tremie.

After the bit and drill pipe are retrieved from the hole as smoothly and quickly as possible,
measure the total depth of the hole to verify its depth and to check its stability.

Suspend the well screen and casing in the hole by the use of hoisting bail in order to ensure
proper depth and a plumb construction. This may be unnecessary for wells less than 30 feet
in depth. Place the casing and screen in the hole as fast as is safely possible to minimize the
time that the borehole stays open.

Prior to the addition of filter pack, cover the top of the well casing to prevent filter pack
material from entering the well casing.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
29 of 44

Use a tremie pipe for placement of filter pack, bentonite, and grout. Also emplace the filter
pack and bentonite seal as soon as possible to avoid potential collapse of the hole.

Slowly pour the filter pack into the tremie pipe to avoid bridging within the tremie pipe at
the water table. The level of the top of the filter pack shall be constantly tagged with
measuring tape as the filter pack is being emplaced.

Make the bentonite seal at least 3 feet thick. It should consist of bentonite pellets or chips
emplaced through the tremie pipe. Tag the level of the bentonite periodically to ensure
accurate placement. If the bentonite seal is less than 10 feet bgs and the borehole is stable,
the bentonite may be placed directly from the top of the borehole rather than through the
tremie pipe.

After allowing 15 minutes for the bentonite seal to hydrate, emplace a grout seal through the
tremie pipe from the top of the bentonite seal to within 2 feet of ground surface. The grout
shall be placed from bottom to top in one continuous pour. If the top of the bentonite seal is
less than 10 feet bgs, and the borehole is not subject to collapse and is not filled with drilling
fluid, the grout may be placed directly from the top of the borehole. The composition of the
grout is detailed in Section 5.4.5.

Construct an above- or below-ground wellhead.

Potential Problems and Solutions

Bridging Filter Pack or Bentonite Seal

Bridging filter pack or bentonite can create unwanted void spaces that might collapse in the future.

Controlled pouring of the annular materials is the best solution for bridging. In the case of mud
rotary, however, it may be necessary to perform emplacement of the filter pack and bentonite chips
or pellets through the borehole without the aid of a tremie pipe. For wells greater than 10 feet deep,
obtain the approval of the QA Manager or Technical Director.

5.6.9.3 Air Rotary and Air Rotary With Casing Hammer
General well installation techniques using ARD or ARCH are listed below:

Prepare a pre-installation design drawing in accordance with Section 5.4.1.

Prior to well installation, properly decontaminate and measure the well screen, cap, and
casing to ensure the accurate placement of well casing and screen.

Remember that with ARD techniques, wells are constructed in the borehole after the bit and
drill pipe are removed from the hole. With ARCH, the driven casing remains in the ground
and is slowly withdrawn as well installation proceeds.

After the bit and drill pipe are retrieved from the hole as smoothly and quickly as possible,
measure the total depth of the hole to verify its depth and to check its borehole stability.

To ensure proper depth and a plumb construction, suspend the well screen and casing in the
hole using a hoisting bail. Place the casing and screen in the borehole as fast as is safely
possible to minimize the time that the hole stays open, particularly for ARD.

Solution

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
30 of 44

Before adding filter pack, cover the top of the well casing to prevent filter pack material
from entering it.

For ARD, use a tremie pipe for placement of filter pack, bentonite, and grout. Emplace the
filter pack and bentonite seal as soon as possible to avoid potential collapse of the hole. For
ARCH, the annular materials can in most cases be placed directly between the driven casing
and the well casing. A tremie pipe is advisable if exacting placement is required.

For ARD, place the tremie pipe within 2 feet of the interval where the filter pack is to be
placed. Slowly pour the filter pack into the tremie pipe to avoid bridging within the tremie
pipe at the water table. The tremie pipe shall be slowly withdrawn during placement.

Periodically tag the level of the top of the filter pack with measuring tape while the filter
pack is being emplaced. Install bentonite in a similar manner.

For ARCH, pour the filter pack slowly between the well casing and driven casing. The
driven casing shall be withdrawn periodically while the filter pack is being emplaced.
Withdraw the driven casing in increments no greater than 2 to 3 feet.

For ARD, emplace bentonite pellets or chips through the tremie pipe to a minimum thickness
of 3 feet. Tag the level of the bentonite periodically to ensure accurate placement. For each
foot of bentonite seal installed in an unsaturated completion, add 5 gallons of water of
known chemical quality into the well to hydrate the bentonite. If the bentonite seal is less
than 10 feet bgs and the borehole is stable, the bentonite may be emplaced directly from the
top of the borehole rather than through the tremie pipe. For ARCH, emplace the bentonite
between the well casing and the driven casing while the driven casing is being withdrawn.

Emplace a grout seal through the tremie pipe for the ARD method or through the driven
casing for the ARCH method. Emplace the grout from the top of the bentonite seal to within
2 feet of ground surface. The driven casing or tremie pipe shall be withdrawn as the grout is
placed. Emplace the grout from bottom to top in one continuous pour following placement of
the bentonite seal. If the top of the bentonite seal is less than 10 feet bgs and the borehole is
not subject to collapse, emplace the grout directly from the top of the borehole. The
composition of the grout is detailed in Section 5.4.5.

Construct an above- or below-ground wellhead.

Potential Drilling Problems

Bridging Filter Pack or Bentonite Seal

Bridging filter pack or bentonite can create unwanted void spaces that might collapse in the future.

Controlled pouring of the annular materials is the best solution against bridging.

Heaving Sediment

Fine-grained saturated materials that might cause heaving problems are common in coastal areas.
Difficulties caused by heaving sediments might create problems when drilling with ARCH. Heaving
sediments cannot be drilled using ARD techniques.

Solutions

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
31 of 44

Solutions for Heaving Sediments

Over-drill the borehole by 5 or 10 feet to provide space for heaving sediments to fill in while
well completion is begun.

Add clean water to a level above the water table to create a downward pressure on the
heaving materials. The volume of water added should be extracted during well development.

Heaving sands may also be controlled by first removing the drill pipe from the hole, and then
constructing an airlift line made from the tremie pipe. If there is sufficient water above the
heaving sands, an air line connected approximately 10 feet from the bottom of the tremie
pipe can be used to air lift out the fine-grained sediments at the base of the casing.

Begin placement of filter pack as soon as possible and add it quickly until the over-drilled
space is filled.

5.6.9.4 DTCH

General well installation techniques using DTCH are listed below:

Prepare a pre-installation design drawing in accordance with Section 5.4.1.

Prior to well installation, measure the well screen, cap, and casing to ensure accurate depth
placement of well casing and screen. Place a mark near the top of the casing to identify to
the drillers the proper position to place the casing and screen.

Like HSA drilling techniques, wells are constructed within the dual tube pipe as the pipe is
removed from the ground.

Prior to setting the casing and screen in the hole, verify total depth of the hole by measuring
it and check for surging materials. Suspend the well screen and casing in the hole using a
hoisting bail in order to ensure proper depth and plumb construction.

Prior to addition of filter pack, cover the top of the well casing to prevent filter pack material
from entering the well casing.

The inner pipe of the dual tube assembly shall act as tremie pipe for placement of filter pack,
bentonite, and grout.

Slowly pour the filter pack between the inside of the augers and the outside of the well
casing to avoid potential bridging of the annular materials. While the filter pack material is
being poured, the dual tube pipe shall be incrementally withdrawn. The rate of pipe
withdrawal and filter pack emplacement shall allow for the top of the filter pack level to be
just below the shoe of the dual tube assembly. The level of the top of the filter pack shall be
constantly tagged with measuring tape.

Use bentonite pellets or chips to construct the well seal, which shall be a minimum of 3-feet
thick, and shall also be emplaced through the dual tube assembly. For each foot of bentonite
seal installed in an unsaturated completion, 5 gallons of water of known chemical quality
shall be poured into the well to hydrate the bentonite. Tag the level of the bentonite
periodically to ensure accurate emplacement. If the bentonite seal is less than 10 feet bgs and
the borehole is stable, the bentonite may be emplaced directly from the top of the borehole
rather than through the tremie pipe.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
32 of 44

Emplace a grout seal through the dual tube assembly from the top of the bentonite seal to
within 2 feet of ground surface. Emplace the grout from bottom to top in one continuous
pour immediately following emplacement of the bentonite seal. If the top of the bentonite
seal is less than 10 feet bgs, the grout may be emplaced directly from the top of the borehole.
The composition of the grout is detailed in Section 5.4.5.

Construct an above- or below-ground wellhead.

Potential Problems and Solutions

Bridging Filter Pack or Bentonite Seal

Bridging filter pack or bentonite can create unwanted void spaces or lock the well casing and dual
tube pipe together.

Avoidance of Locked Well Casing

Tag carefully and always keep the filter pack just below the shoe while inching the dual tube
assembly up and slowly adding sand.

Use a smaller-diameter well casing.

Use a filter pack with a larger grain size.

Add water while pouring the sand filter pack. Avoid this unless absolutely necessary.

Solutions for Unlocking Well Casing from Dual Tube Pipe

Insert a surge block into casing and gently surge the water column if the bridge is below
water table.

Add water between the well and piping if the sand bridge is above the water table.

Attach an air compressor to a tremie pipe, and gently blow the bridge away.

Heaving, Surging Materials

Fine-grained saturated materials that might cause surging problems are common in coastal areas.
Heaving sediments might cause problems when drilling with DTCH.

Solutions for Heaving Sediments

Over-drill the borehole by 5 or 10 feet to provide space for heaving sediments to fill in while
well completion begins.

Add clean water to a level above the water table to create a downward pressure on the
heaving materials. The volume of water added should be extracted during well development.

Remove the drill pipe from the hole, and then construct an airlift line made from the tremie
pipe. If there is sufficient water above the heaving sands, an air line connected
approximately 10 feet from the bottom of the tremie pipe can be used to air lift out the fine-
grained sediments at the base of the casing.

Begin emplacement of the filter pack as soon as possible, and add it quickly until the over-
drilled space is filled.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
33 of 44

5.6.10 Well Construction Record Keeping Procedures

A written well completion record (Figure I-C-l-5) detailing the timing, amount of materials, and
methods of installation/construction for each step of monitoring well construction shall be prepared
during construction of each monitoring well by the FM or designate. Construction records shall be
kept in a hard-bound field notebook dedicated to the CTO. An "as-built" drawing illustrating the
placement location and amounts of all materials used in construction of each monitoring well shall
be prepared in the field at the time of construction. The well construction record shall be filled out
with indelible ink. Construction records shall include the date/time and quantities of materials used at
each of the following stages of monitoring well construction, including:

Drilling

Drill rig type

Drilling method/coring method
Drill bit/core barrel diameter (hole diameter)

Drill company, driller, helper(s)

Field geologist, supervising geologist

Dates/times start and finish drilling hole, interval drilling rates
Total depth of hole

Drilling location, surveyed ground elevation
Inclination of hole from horizontal
Borehole abandonment - type, volume, and surface seal
Casing material - type

Casing decontamination - document process and equipment used
Casing diameter - nominal I.D. of casing
Screen material
Type

Top and bottom of section as actually installed
Length

Slot type, size, shape
Type of bottom plug and/or cap used
Filter pack material

Composition and size gradation
Manufacturer

Actual volume and depth of top and bottom of filter pack

Calculated volume versus actual volume used and explanation of discrepancies

Transition seal

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
34 of 44

Composition and depth of top and bottom of seal

Size (or gradation) or material used (e.g., pellets, granulated, or powdered)

Time allowed for hydration prior to emplacement of annular grout slurry seal
Annular slurry seal

Date and time of beginning and completion of annular seal
Type and actual volume of seal

Calculated volume versus actual volume and explanation of discrepancies
Set time allowed prior to commencement of additional work
Surface completion

Type of construction

Nature of materials used for surface completion
Date/time of completion

5.6.11 Well Location

A registered land surveyor shall survey each monitoring well location for exact horizontal location to
the nearest 0.5 foot, and exact vertical location to the nearest 0.01 foot, referenced to mean sea level
or mean low low water. The vertical elevation shall be surveyed between the two notches cut in the
top of the well casing, which is the point from which all water level measurements shall be made.
The elevation of the ground or top of the concrete slab adjacent to the monitoring well shall also be
surveyed, to the nearest 0.01 foot.

5.7 Well Abandonment/Destruction

Once a monitoring well is no longer needed as part of an investigation, or has been damaged to the
extent that it cannot be repaired, it is essential that it be properly abandoned. The proper
abandonment of a monitoring well ensures that the underlying groundwater supply is protected and
preserved. In addition, proper well abandonment eliminates a potential physical hazard and liability.
An additional permit and/or inspection may be required for abandonment, depending on state or local
regulations.

The standard procedures for the abandonment of a groundwater monitoring well apply to the HSA
drilling method. This type of installation was chosen because it is the primary method of abandoning
groundwater monitoring wells. For wells abandoned on Guam, the current Guam Environmental
Protection Agency Well Abandonment Procedures shall be followed (Attachment I-C-l-1).

The first step in abandoning a groundwater monitoring well is to remove the surface completion
from around the top of the well casing. This is normally accomplished using a jackhammer to break
the surface cement seal, and then removing the monument or traffic box. When the surface seal and
the wellhead cover have been removed, over-drill the well to its total depth using HSAs. Once the
total depth of the well has been reached, remove the casing and screen from the borehole. Then
completely backfill the borehole with a grout seal. Typically, the grout seal is emplaced as slurry of
Portland cement grout, which contains a minimum of 3 to 5 percent bentonite as described in

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
35 of 44

Section 5.4.5. When mixing the slurry, take care that the bentonite is mixed according to the
manufacturer's specifications to ensure the proper consistency.

Emplace the slurry through the HSAs. The rates at which the augers are withdrawn and the slurry is
added shall be such that the level of the slurry within the borehole is just below the lead auger. The
borehole seal shall extend from the total depth of the borehole to a depth of approximately 1 foot
bgs. Then repair the surface to prior conditions and grade.

If the monitoring well casing cannot be pulled or drilled out, perforate the well casing adjacent to the
saturated zones so that the annular space and any nearby voids can be filled with sealing material.
Fill the perforated well or borehole from the bottom up with an appropriate sealing material, such as
neat cement. Inject the neat cement under pressure to force it into the annular space, nearby voids,
and filter pack. Apply pressure for a sufficient time to allow the cementing mixture to set. After the
cement has hardened, excavate a hole around the well (use a backhoe if necessary) to the depth
specified in the Monitoring Well Abandonment Work Plan (WP) and ensure the excavation depth is
in accordance with local regulatory agency guidelines (Attachment 1 for Guam Monitoring Well
Abandonment Procedure) (GEPA 2006). Remove the uppermost portion of the casing, (if still in
place), and pour a cement cap on top of the abandoned well, and backfill the remaining portion of the
excavation with sealing material. Note, if personnel are required to enter the excavation to remove
the upper portion of the casing, then proper sloping and shoring are required as per Section 25,
Excavations of The Safety and Health Requirements Manual EM 385-1-1 (USACE 2008).

The State of Hawaii Department of Health Hazard Evaluation and Emergency Response must be
notified at least 1 week prior to any well abandonment activities conducted in Hawaii (DOH 2009,
Section 6.2.5.1). Additionally, an Abandonment of Monitoring Well Summary Report should be
prepared using the form presented in Attachment l-C-1-2. The record should include the following
information:

Well construction information:

Date of installation
Drilling company
Total depth
Casing material/length
Screen material/length
Annular material

General abandonment information:

Drilling firm (contact, mailing address, and phone number).

Consulting firm (contact, mailing address, and phone number).

Well abandonment information
Date of abandonment
Reason for abandonment

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
36 of 44

Details of how the casing/screen was removed drilled out or perforated.

Sealing material (weight/volume/bags/mix ratio)

5.8	Vapor Extraction/Monitoring Wells

Vapor extraction/monitoring wells have most of the same design and installation considerations and
procedures as groundwater-monitoring wells, with the exception that they are screened in the
unsaturated zone. Vapor extraction/monitoring wells generally shall not be screened over an interval
greater than 20 feet and shall not be screened over two or more lithologies that have air
permeabilities that differ by more than one order of magnitude. Vapor extraction/monitoring wells
shall be installed using drilling techniques that do not require drilling fluids other than filtered air.
Vapor monitoring wells may have casing I.D.s of 2 inches or less while extraction wells shall
generally have casing I.D.s of at least 4 inches. The design of vapor extraction/monitoring wells is
dependent upon many site-specific factors, such as the depth of contamination, soil conditions,
geology, and depth to groundwater. As a result, specifics related to the design of these wells shall be
included in the CTO WP, field sampling plan, or plans and specifications.

5.9	Drive Points

An alternative to conventional monitoring well construction is, under limited conditions, the use of
drive points. These consist of slotted steel pipe that is pushed, hammered, or hydraulically jetted into
the ground. A filter pack is not constructed around the screen, so the width of the screen openings
must be sufficiently small to prevent the passage of significant quantities of sediment into the well
during the withdrawal of water for sampling. In some instances, the drive points are used only as
piezometers.

Drive points are commonly used in hazardous waste investigations to sample ambient soil gases in
the vadose zone. It is often possible to extend the drive point below the water table to collect water
samples. In some instances, permits may be required because the drive points are considered in some
jurisdictions to be equivalent to a temporary monitoring well.

5.10	Discrete Depth Groundwater Sampling

Another alternative to conventional monitoring well construction is the use of a discrete groundwater
sampling device such as a Hydropunch. The Hydropunch tool can be used in conjunction with a
standard drill rig, a cone penetrometer rig, or possibly a vehicle capable of driving vapor probes to
sample groundwater and non-aqueous phase liquid in unconsolidated formations. The Hydropunch
tool is constructed of a stainless steel drive point, a perforated section of Teflon pipe for a sample
intake, and a stainless steel sample chamber. The tool is 55.5 inches long, 2 inches in O.D., and
weighs approximately 24 pounds.

Ideally, a standard HSA drilling rig is used to drill a pilot hole to a depth just above the desired
sampling depth. The Hydropunch tool is then hydraulically pushed or driven 4 to 5 feet through the
saturated zone at each sampling location. As the tool is advanced, the sample intake screen remains
pristine within the watertight stainless steel chamber. When the desired sampling interval is reached,
the steel sampling chamber is unscrewed and withdrawn 1 foot to several feet, depending on how
long a sampling interval is needed. This exposes the intake screen to the groundwater. Under
hydrostatic pressure, groundwater flows through the intake screen and fills the sample chamber,

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
37 of 44

without aeration or agitation occurring. The drive cone, which is attached to the base of the screen,
will remain in place by soil friction.

The pointed shape of the sampler and its smooth exterior surface prevent downward transport of
surrounding soil and groundwater as the tool is advanced. Once in place, the intake screen will be
sealed from groundwater above and below the interval being sampled, because the exterior of the
Hydropunch tool is flush against the surrounding soil wall. Additionally, as the tool is advanced, the
sample intake screen is retained within the steel watertight sample chamber.

A stainless steel or Teflon bailer with a bottom check valve is lowered into the sample chamber to
collect the groundwater sample. Groundwater is then decanted at ground surface from the bailer into
the appropriate sample containers.

6.	Records

Monitoring well location, design, and construction shall be recorded in the field notebook for the
CTO and on a well completion record form (Figure I-C-l-5). The field operations manager should
provide a copy of this form to the CTO Manager for the project files.

7.	Health and Safety

Field personnel shall perform work in accordance with the current (or as contractually obligated)
United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2008) and site-specific health and safety plan.

8.	References

ASTM International (ASTM) 2010. Standard Practice for Design and Installation of Ground Water
Monitoring Wells. D5092-04el(Reapproved 2010). West Conshohocken, PA.

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

Department of Health, State of Hawaii (DOH). 2009. Technical Guidance Manual for the
Implementation of the Hawaii State Contingency Plan. Interim Final. Honolulu: Office of Hazard
Evaluation and Emergency Response. 21 June.

Department of the Navy (DON). 2010. Ammunition and Explosives Safety Ashore. NAVSEA OP 5
Volume 1, 7th Revision, Change 11. 0640-LP-108-5790. Commander, Naval Sea Systems
Command. July 1.

	.2014. Environmental Readiness Program Manual. OPNAV Instruction 5090. ID. 10 January.

Guam Environmental Protection Agency (GEPA). 2006. Well Abandonment Procedure. Water
Resources Management Program.

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
38 of 44

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-A-5, Utility Clearance.

Procedure I-B-l, Soil Sampling.

Procedure I-B-5, Surface Water Sampling.

Procedure I-F, Equipment Decontamination.

9. Attachments

Attachment I-C-l-1, Guam Monitoring Well Abandonment Procedure
Attachment I-C-l-2, DOH Abandonment of Monitoring Well Summary Report Form

-------
Attachment l-C-1-1
Guam Well Abandonment Procedure

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program

Monitoring Well Installation and Abandonment

Procedure Number:
Revision Date:
Page:

l-C-1
May 2015
41 of 44

/|£\

Well Abandonment Procedure





Guam Environmental Protection Agency



w

Water Resources Management Program

W7

I. Abandonment procedure for cased wells that mil not have its casing removed

1.	Remove the well pedestal and concrete pad if applicable.

2.	Bxcavatc down to six (6) feet and cut the casing.

3.	It' the well extends into the water table, measure the depth to the water table(DWT) and fill
the well with 3/8 to 3/4 inch clean washed aggregate to three (3) feet above the water table.
If the well is completely within the vadose zone, proceed to item "1.4,"

4.	Provide a two-foot (2) a bentonite plug by placing 3/4 inch bentomte chip in six (6) inch lifts
and hydrating w ith potable water.

5.	Fill the casing with clean cement up to six (6) below the ground surface which will form a
mushroom cap.

6.	Fill the final six (6) feet with native soil.

Note: a, For wells with a depth to the water table greater than eleven (11) feet, the total depth
of fill for item "1.5" will lie equal to DWT less eleven feet.

b.	For shallow wells with a depth to the water tabic greater than nine (9) feet, but less
than eleven (11) feet above the water table, item "1.5" will not be included.

c.	For shallow wells with a depth to the water table greater than three (3) feet, but less
than nine (9) feet, items "1.4" and '1.5" will not be included.

II. Abandonment procedure for wells that will have its casing removed and open

boreholes.

1.	Remove the old pedestal and concrete pad if applicable.

2.	Remove the casing if not an open borehole.

3.	If the well extends into the water table, measure the depth to the water table(DWT) and fill
the well with 3/8 to 3/4 inch clean washed aggregate to three (3) feel above die measured
water table. If the well is completely within the vadose zone, proceed to item "11.4."

4.	Provide a two-foot (2) bentonite plug by placing 3/4 inch bentonite chips in six (6) inch lifts
and hydrating with potable water.

5.	Fill the remaining portion with bentonite/cement slum' (30% of bentonite by volume) in 10-
foot lifts up to twenty-six (26) feet below the ground surface.

a,	After each 10-foot lift, the hole shall be sounded to determine if ten (10) feel of the
hole is actually tilled with the bentonite/cement slum' by at least eight (8) feet. If the
depth of the fill is greater than eight (8) feet, continue with the next ten-foot (10) lift
of bentonite/cement slurry. If the depth of the fill is less than eight (8) feet (an
indication that there is a cavity), go to "II.5.b Otherwise, continue with item
"II.5.a." When the bentonite/cement fill reaches a height of twenty-six (26) feet
below the ground surface, go to item "11.6"

b.	Fill the next ten (10) feet with 3/8 to 3/4 inch clean washed aggregate Sound the
hole to ensure that at least nine (9) feet has been filled with clean aggregate. If less
than nine (9) feet is filled, repeat another ten-foot (10) lift of 3/8 to 3/4 inch clean
washed aggregate until the sounding of the well/borehole reveals a rise of nine (9)
feet or greater. Go to item "ll.S.c."

-------
NAVFAC Pacific ER Program	Procedure Number:	l-C-1

Monitoring Well Installation and Abandonment	Revision Date:	May 2015

Page:	42 of 44

c. Provide a two-foot (2) bentonite plug above the clean aggregate by placing 3/4 inch
bentonite chips in six (6) inch lifts and hydrating with potable water. Continue with
item "H5.a."

6.	Fill the next twenty (20) feet above the bentonite/cement fill with neat cement.

7.	The remaining six (6) feet shall be filled with native soil.

Note: a. For wells with a depth to the water table greater than thirty-one (31) feet, the total
depth of fill for item 'H.5" will be equal to D WT less thirty-one (31) feet.

b.	For shallow wells with a depth to the water table greater than eleven (11) feet, but
less than thirty-one (31) feet above the water table, item "II.5" will not be included.

c.	For shallow wells with a depth to the water table greater than nine (9) feet, but less
than eleven (11) feet above the water table, items "II.5" and "11.6" will not be
included.

d.	For shallow wells with a depth to the water table greater than three (3) feet, but bss
than nine (9) feet, items '11.4", "II.5" and "II.6" will not be included.

General Notes:

a.	The driller shall submit a well abandonment plan following the above procedure to Guam
EPA for review/approval.

b.	The driller shall notify Guam EPA administrator 48 hours prior to starting date of the the
approved abandonment plan.

c.	All above-ground materials shall be removed from the well site and disposed in a manner that
conforms to the Guam EPA's solid waste regulations.

d.	If a well is in an area that is covered with asphalt or concrete that is not to be removed (such
as a parking lot or a driveway/street), the native soil fill may be excluded and the well may be
filled to the top with neat cement and then covered with new asphalt or concrete.

-------
Attachment l-C-1-2

DOH Abandonment of Monitoring Well Summary Report Form

-------
This page intentionally left blank

-------
Abandonment of Monitoring Well Summary Report

iw/

(Monitoring Well ID)







Submit form within 30 days of well abandonment or within 90 days if included in a site closure, monitoring, or investigation report.
In addition, submit copies of the original boring log and well construction diagram for the monitoring well, a site map showing the
location of the abandoned monitoring well, and the disposal documentation for wastes generated during the abandonment process.
Submit all documentation to: Hawaii Department of Health, Hazard Evaluation and Emergency Response Office, Attention: SDAR,
919 Ala Moana Blvd, Rm. 206, Honolulu Hawaii 96814.

1.million 1 n rn

Oiwii'i' In I'o ini ill inn

Facility Name:

Well Owner:

Facility Address:

Contact Person:



Mailing Address:

Latitude:



Longitude:

Phone Number:

Fax Number:

TMK:

Land Owner:

Location Description:

Contact Person:



Mailing Address:





Monitoring Well Location Map Attached: Y N

Phone Number:

Fax Number:

Will ( iiiislnniiim 1 iiIVii-iiiiiliini

Date of Installation:

Casing Material:

Casing Diameter:

Drilling Company:

Casing Length:

Casing Depth:

Lotal Depth:

Screen Material:

Slot Size:

Depth to Water:

Screen Length:

Screen Depth:

Was the Well Set in an Aquifer that is a Current or Potential

Annular Material:

Depth:

Drinking Water Source: Y N

Annular Material:

Depth:

Boring Log/Well Construction Diagram Attached: Y N

Annular Material:

Depth:

(li'iKTiil Al>;iikIiiiiiiionI 1 iirn

Drilling Firm:

Consulting Firm:

Contact Person:

Contact Person:

Mailing Address:

Mailing Address:





Phone Number: Fax Number:

Phone Number:

Fax Number:

Will Al)iiii(l(iniiii-nl InlViiiiiiiiinii

Date of Abandonment:

Sealing Material:

Depth:

Reason for Abandonment:

Volume/Weight/Bags

Mixing Ratio:

Casing/Screen Removed: Y N

Sealing Material:

Depth:

If Yes, was annular material removed?: Y N

Volume/Weight/Bags

Mixing Ratio:

If No, was casing cut off below the surface?: Y N

Method of Sealing Material Placement:

Comments:



Driller's Signature:

Date:



Consultant's Signature:

Date:



Version: September 2005

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Procedure Number:

Revision:

Page:

l-C-2
May 2015
1 of 13

Monitoring Well Development

1.	Purpose

This section describes the standard operating procedures for monitoring well development to be used
by United States Navy Environmental Restoration (ER) Program, Naval Facilities Engineering
Command (NAVFAC), Pacific personnel.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the Uniform Federal Policy-Quality Assurance Project Plan
(DoD 2005). As professional guidance for specific activities, this procedure is not intended to
obviate the need for professional judgment during unforeseen circumstances. Deviations from this
procedure while planning or executing planned activities must be approved and documented by the
following prime contractor representatives: the CTO Manager and the Quality Assurance (QA)
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

3.	Definitions

None.

4.	Responsibilities

The prime contractor CTO Manager is responsible for ensuring that these monitoring well
development procedures are followed during projects conducted under the NAVFAC Pacific ER
Program. The CTO Manager is responsible for ensuring that all personnel involved in monitoring
well development shall have the appropriate education, experience, and training to perform their
assigned tasks as specified in Chief of Naval Operations Instruction 5090.1, under Specific Training
Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The Field Manager is responsible for ensuring that all project field staff follow these procedures.

Field personnel are responsible for the implementation of this procedure.

5.	Procedure

5.1 Introduction

Well development procedures are crucial in preparing a well for sampling. They enhance the flow of
groundwater from the formation into the well and remove the clay, silt, and other fines from the
formation so that produced water will not be turbid or contain suspended matter that can interfere
with chemical analyses. A monitoring well should be a "transparent" window into the aquifer from

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Procedure Number:

Revision:

Page:

l-C-2
May 2015
2 of 13

which samples can be collected that are truly representative of the quality of water that is moving
through the formation.

The goal of well development is to restore the area adjacent to a well to its natural condition by
correcting damage to the formation during the drilling process. Well development shall accomplish
the following tasks:

Remove a filter cake or any drilling fluid within the borehole that invades the formation.
Remove fine-grained material from the filter pack.

Increase the porosity and permeability of the native formation immediately adjacent to the

Well development shall not occur until 24 hours after the completion of well installation to allow the
annular seal to fully set up.

5.2 Factors Affecting Monitoring Well Development

5.2.1	Type of Geologic Materials

Different types of geologic materials are developed more effectively by using certain development
methods. Where permeability is greater, water moves more easily into and out of the formation and
development is accomplished more quickly. Highly stratified deposits are effectively developed by
methods that concentrate on distinct portions of the formation. If development is performed
unevenly, a groundwater sample will likely be more representative of the permeable zones. In
uniform deposits, development methods that apply powerful surging forces over the entire screened
interval will produce satisfactory results.

5.2.2	Design and Completion of the Well

Because the filter pack reduces the amount of energy reaching the borehole wall, it must be as thin as
possible if the development procedures are to be effective in removing fine particulate material from
the interface between the filter pack and natural formation. Conversely, the filter pack must be thick
enough to ensure a good distribution of the filter pack material during emplacement. The general rule
is that filter pack material must be at least 2 inches thick.

The screen slot size must be appropriate for the geologic material and filter pack material in order for
development to be effective. If slot size is too large, the removal of too much sediment may cause
settlement of overlying materials and sediment accumulation in the casing. When screen openings
are too small, full development may not be possible and well yield will be below the potential of the
formation. Additionally, incomplete development coupled with a narrow slot size can lead to
blockage of the screen openings.

5.2.3	Drilling Method

The drilling method influences development procedure. Typical problems associated with specific
drilling methods include the following:

If a mud rotary method is used, mud cake builds up on the borehole wall and must be
removed during the development process.

filter pack.

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Procedure Number:

Revision:

Page:

l-C-2
May 2015
3 of 13

If drilling fluid additives have been used, the development process must include an attempt
to remove all fluids that have infiltrated into the native formation.

If driven casing or hollow-stem auger methods have been used, the interface between the
casing or auger flights and the natural formation may have been smeared with fine
particulate matter that must be removed during the development process.

If an air rotary method has been used in rock formations, fine particulate matter is likely to
build up on the borehole walls and may plug pore spaces, bedding planes, and other
permeable zones. These openings must be restored during the development process.

5.3 Preparation

In preparing for monitoring well development, development logs for any other monitoring wells in
the vicinity should be reviewed to determine the general permeability of the water-bearing formation
and the appropriate development method.

Depth to groundwater and information from the well construction log should be used in calculating
the required quantity of water to be removed. The distance between the equilibrated water level and
the bottom of the screen is the saturated section. The saturated section (feet) multiplied by the unit
well volume per foot (gallons/linear foot) equals the gallons required to remove one total well
volume of water. The unit well volume is the sum of the casing volume and the filter pack pore
volume, both of which depend upon casing and borehole diameter and the porosity of the filter pack
material. Well volume can be calculated using Table I-C-2-1, Table I-C-2-2, or Table l-C-2-3.

Table l-C-2-1: Casing Volume*

Casing Diameter (inches)

Volume (gallon/linear foot)

2

0.16

4

0.65

6

1.47

Table l-C-2-2: Filter Pack Pore Volume

Casing Diameter (inches)

Borehole Diameter (inches)

Volume a (gallon/linear foot)

2

6

0.52

2

8

0.98

4

10

1.37

4

12

2.09

6

12

1.76

* The above two volumes must be added together to obtain one unit well volume.
a Assumes a porosity of 40% for filter pack.

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Table l-C-2-3: Well Volume Calculation

HOLE DIAMETER	dh

WELL CASING	rl ID =

INSIDE DIAMETER	w

OUTSIDE DIAMETER	d„OD = 	

DEPTH TO:	H
WATER LEVEL

BASE OF SEAL	S " 	

BASE OF WELL	TD

EST. FILTER PACK POROSITY	p = 	

Procedure Number: l-C-2
Revision:	May 2015

Page:	4 of 13

WELL VOLUME CALCULATION:

CASING VOLUME = V. = n[ j (TD - H) = 3. l/¦— | (_

FILTER PACK PORE VOLUME = Vf = EI ( y j - f

(TD - (Sor H*)(p)

(* if S > H, use S; if S < H, use H)

= 3.14

L

TOTAL WELL VOLUME = VT = Vc + Vf

ft.3 x 7.48 =

gal.

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Procedure Number:

Revision:

Page:

l-C-2
May 2015
5 of 13

5.4	Decontamination

The purpose of decontamination of development equipment is to prevent cross-contamination
between monitoring wells. Use disposable equipment where appropriate. Use a steam-cleaner, if
available, to decontaminate development equipment. Clean the equipment away from the monitoring
well in such a fashion that decontamination effluent can be intercepted and drummed.

A triple rinse decontamination procedure is acceptable for equipment, such as bailers, or if access to
a steam cleaner is not possible (Procedure I-F, Equipment Decontamination).

During well development, place visqueen around the well to prevent contamination at ground
surface. Properly dispose of this sheeting after each use.

5.5	Well Development Monitoring

Throughout the well development process, maintain a development record using the form presented
in Attachment I-C-2-1. The record should include the following information:

General:

Project name and number
Well name/number and location
Date, time, and weather conditions
Names of personnel involved
Development volume:

Initial and final water level
Casing total depth and diameter
Borehole diameter

Casing volume, filter pack pore volume, total well volume
Volume of water to be evacuated
Method and rate of removal
Appearance of water before and after development
Monitoring data for each sample point:

Date, time, elapsed time

Cumulative gallons removed, removal method, removal rate

Temperature, pH (indicates the hydrogen ion concentration - acidity or basicity),
specific conductivity, turbidity, dissolved oxygen, redox potential, and salinity

Part of the well development procedure shall consist of acquisition and analysis of water samples at
appropriate intervals considering the total quantity of water to be removed. Measure conductivity,
pH, temperature, dissolved oxygen, redox potential, turbidity, and salinity in each sample using a
multi-parameter meter and flow-through cell. Collect readings on a periodic basis (approximately
every 3 to 5 minutes) during development and obtain at least one reading after removal of each well

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Procedure Number:

Revision:

Page:

l-C-2
May 2015
6 of 13

volume. At the time each sample is analyzed, record the cumulative water removed, the time, the
time elapsed during development, and calculated flow rate. Continue development until at least
3 borehole volumes have been removed, turbidity stabilizes at or below 5 nephelometric turbidity
units, and three successive readings of the parameters have stabilized (values within 10 percent of
each other). If stabilization has not been attained, if turbidity remains high, or if the well does not
readily yield water, allow the water level in the well to recover, conduct an additional 15 minutes of
mechanical surging and/or bailing, then continue development until stabilization can be achieved or
for a reasonable time.

Section 5.7 describes well development in special situations, such as low yield formations and 2-inch
wells.

5.6 Methods of Monitoring Well Development

The methods available for the development of monitoring wells have been inherited from production
well practices. Methods include: (1) mechanical surging with a surge block or swab, and (2) surge
pumping. Development methods using air or jetting of water into the well are generally inappropriate
for development of monitoring wells due to the potential for affecting water quality.

Containerize and appropriately label all development water (unless it is permissible to discharge it on
site). All development efforts must utilize mechanical surging or surge pumping, followed by bailing
or groundwater removal with a pump. More detailed descriptions of appropriate development
methods are presented below.

5.6.1 Mechanical Surging and Bailing

For mechanical surging and bailing, a surge block or swab is operated either manually or by a drill
rig. The surge block or swab should be vented and be of sufficient weight to free-fall through the
water in the well and create a vigorous outward surge. The equipment lifting the tool must be strong
enough to extract it rapidly. A bailer is then used to remove fine-grained sediment and groundwater
from the well.

Procedures:

1.	Properly decontaminate all equipment entering the well.

2.	Record the static water level and the total well depth.

3.	Lower the surge block or swab to the top of the screened interval.

4.	Operate in a pumping action with a typical stroke of approximately 3 feet.

5.	Gradually work the surging downward through the screened interval during each cycle.

6.	Surge for approximately 10 to 15 minutes per cycle.

7.	Remove the surge block and attach the bailer in its place.

8.	Bail to remove fines loosened by surging until the water appears clear.

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Procedure Number:

Revision:

Page:

l-C-2
May 2015
7 of 13

9.	Repeat the cycle of surging and bailing at least three times or until turbidity is reduced and
stabilization of water quality parameters occurs.

10.	The surging shall initially be gentle and the energy of the action should gradually increase
during the development process.

The advantages (+) and disadvantages (-) of this method are listed below:

+ Reversing the direction of flow reduces bridging between large particles, and the inflow then
moves the fine material into the well for withdrawal.

+ It affects the entire screened interval.

+ It effectively removes fines from the formation and the filter pack.

-	It might cause upward movement of water in the filter pack that could disrupt the seal.

-	Potential exists for damaging a screen with a tight-fitting surge block or with long surge
strokes.

5.6.2 Surge Pumping

Procedures:

1.	Properly decontaminate all equipment entering the well.

2.	Record the static water level and the total well depth.

3.	Lower a submersible pump or airlift pump without a check valve to a depth within 1 to 2 feet
of the bottom of the screened section.

4.	Start pumping and increase discharge rate to maximum capacity (overpumping), causing
rapid drawdown of water in the well.

5.	Periodically stop and start the pump, allowing the water in the drop pipe to fall back into the
well and surge the formation (backwashing), thus loosening particulates.

6.	The pump intake shall be moved up the screened interval in increments appropriate to the
total screen length.

7.	At each pump position, the well shall be pumped, overpumped, and backwashed alternately
until satisfactory development has been attained as demonstrated by reduction in turbidity
and stabilization of water quality parameters.

The advantages (+) and disadvantages (-) of this method are listed below:

+ Reversing the direction of flow reduces bridging between large particles, and the inflow then
moves the fine material into the well for withdrawal.

+ It effectively removes fines from the formation and filter pack.

-	The pump position or suction line must be changed to cover the entire screen length.

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Procedure Number:

Revision:

Page:

l-C-2
May 2015
8 of 13

Submersible pumps suitable to perform these operations may not be available for small
diameter (1 inch or less) monitoring wells.

- It is not possible to remove sediment from the well unless particle size is small enough to
move through the pump.

For additional information on well development, consult the references included in Section 8 of this
procedure.

5.7 Special Situations

5.7.1	Development of Low Yield Wells

Development procedures for monitoring wells in low-yield (<0.25 gallons per minute), water-bearing
zones are somewhat limited. Due to the low hydraulic conductivity of the materials, surging of water
in and out of the well casing is difficult. Also, the entry rate of water is inadequate to remove fines
from the well bore and the gravel pack when the well is pumped. Additionally, the process may be
lengthy because the well can be easily pumped dry and the water level is very slow to recover.

Follow the procedures for mechanical surging and bailing for low yield wells. During surging and
bailing, wells in low yield formations should be drawn down to total depth twice, if possible.
Development can be terminated, however, if the well does not exhibit 80 percent recovery after
3 hours.

5.7.2	Development of 2-inch Wells

It is easier to develop monitoring wells that are large in diameter than small diameter wells.
Mechanical surging or bailing techniques that are effective in large diameter wells are much less
effective when used in wells 2 inches or less in diameter. Mechanical surge blocks and bailers have a
high potential for damaging a small diameter well. As a result, the CTO Manager shall obtain
approval from the QA Manager or Technical Director prior to installing groundwater monitoring
wells with inside diameters of 2 inches or less.

Develop two-inch or smaller diameter wells by surging with a specially designed, hand-operated
surge block or by pumping with a bladder or airlift pump. Information related to development of
wells 2 inches or less in diameter shall be included in the CTO work plan.

6.	Records

Well development information should be documented in indelible ink on well development
monitoring forms (Attachment I-C-2-1). Copies of this information shall be sent to the CTO
Manager and to the project files. The CTO Manager shall review all well development logs on a
minimum monthly basis.

7.	Health and Safety

Field personnel shall perform work in accordance with the current (or as contractually obligated)
United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2008) and site-specific health and safety plan.

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Procedure Number:

Revision:

Page:

l-C-2
May 2015
9 of 13

8. References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/uip_qapp_vl_0305.pdf.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-F, Equipment Decontamination.

9. Attachments

Attachment I-C-2-1: Well Development Record

-------
This page intentionally left blank

-------
Attachment l-C-2-1
Well Development Record

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Monitoring Well Development

Procedure Number:

Revision:

Page:

l-C-2
May 2015
13 of 13

WELL DEVELOPMENT LOG

PROJECT

WELL ID

SITE

PREPARED BY

METHOD

OVERPUMPAGE ~

BAILER ~
SURGE

BLOCK ~
AIR LIFT ~
OTHER

INITIAL WATER LEVEL:
INITIAL TOTAL DEPTH:

FINAL WATER LEVEL:
FINAL TOTAL DEPTH:

REMARKS:

•CAPACITY OF

CASING
(GALLONS/LINEA
R FOOT)

1"-0.012
2"-0.16
4" - 0.65
6"-0.1.47

•VOLUME BETWEEN CASING AND HOLE
(GALLONS/LINEAR FOOT)

(ASSUMING 40% POROSITY)

1" CASING AND 2" HOLE - 0.013
2" CASING AND 6" HOLE - 0.52
2" CASING AND 8" HOLE - 0.98
4" CASING AND 10" HOLE - 1.37
4" CASING AND 12" HOLE - 2.09

*The two volumes for the saturated portion of the well must be added together to
obtain one unit well volume.



DEVELOPMENT LOG:

CUMULATIVE
WATER
REMOVED

WATER QUALITY

COMMENTS

DATE

TIME

METHOD

ELAPSED
TIME

FLOW
RATE
(gpm)

GALLONS

PH

TEMP
TO

SP. COND
(mS/cm)

DO

(mg/L)

ORP
(mV)

TURBIDITY
(ntu)

SALINITY
(PPt)













































































































































































































































































































































































































































































































































































































DO dissolved oxygen

ORP oxidation-reduction potential

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:

Revision:

Page:

i-D-1
May 2015
1 of 13

Drum Sampling

1.	Purpose

This standard operating procedure describes the methods by which United States Navy
Environmental Restoration (ER) Program, Naval Facilities Engineering Command (NAVFAC),
Pacific personnel will sample drum(s) at hazardous waste and non-hazardous waste sites. Prior to
disturbing and handling drums of unknown origin and/or with unknown contents, approval from the
Navy will be required.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program. As
professional guidance for specific activities, this procedure is not intended to obviate the need for
professional judgment during unforeseen circumstances. Deviations from this procedure while
planning or executing planned activities must be approved and documented by the following prime
contractor representatives: the CTO Manager and the Quality Assurance (QA) Manager or Technical
Director. A Navy project representative (i.e., Remedial Project Manager or QA Manager) shall also
concur with any deviations

3.	Definitions

None.

4.	Responsibilities

The prime contractor CTO Manager is responsible for ensuring that drums of concern are handled
and sampled according to this procedure. The CTO Manager is responsible for ensuring that all
personnel involved in drum sampling have the appropriate education, experience, and training to
perform their assigned tasks as specified in Chief of Naval Operations Instruction 5090.1, under
Specific Training Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The Field Manager is responsible for ensuring that these procedures and the work plan (WP) are
followed when drums are sampled.

Field sampling personnel are responsible for the implementation of this procedure.

5.	Procedures

5.1 Method Summary

Prior to sampling, drums should be inventoried, staged, and opened. Inventorying entails recording
the visible qualities of each drum and any characteristics pertinent to classification of the contents.
Staging involves the organization, and sometimes consolidation, of drums containing similar wastes

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:

Revision:

Page:

i-D-1
May 2015
2 of 13

or that share characteristics. Closed drums may be opened manually or remotely. In the interest of
worker safety, it is required to open drums remotely unless the drum contents are known not to
present any potential physical or chemical threat to workers. Analytical results from associated field
samples may be used to evaluate potential threats. The most widely used method of sampling a drum
containing liquids involves the use of a glass thief. This method is quick, simple, relatively
inexpensive, and does not require decontamination. Additional information related to drum sampling
is available in Section 8, References.

5.2	Interference and Potential Problems

The practice of tapping drums to determine their contents is neither safe nor effective and should not
be used. Any necessary air monitoring should be conducted when working near over-pressurized
drums.

Do not move drums that are over-pressurized to the extent that the head is swollen several inches
above the level of the chime (the protruding rings at the top and bottom of the drum). A number of
devices have been developed for venting critically swollen drums. One method that has proven to be
effective is a tube and spear device. A light aluminum tube (3 meters long) is positioned at the vapor
space of the drum. A rigid, hooking device attached to the tube goes over the chime and holds the
tube securely in place. The spear is inserted in the tube and positioned against the drum wall. A sharp
blow on the end of the spear drives the sharpened tip through the drum, and the gas vents along the
grooves. The venting should be done remotely (e.g., using a backhoe bucket) from behind a wall or
barricade. Once the pressure has been relieved, the bung can be removed and the drum sampled. It is
necessary that personnel experienced in sampling of over-pressurized or unknown drum contents, or
known hazardous waste contents, perform this task. If project team personnel are not experienced in
this type of sampling, it is recommended that a subcontractor experienced in this type of sampling
implement this portion of the sampling.

5.3	Equipment/Apparatus

The following are standard materials and equipment required for sampling:

An approved site-specific sampling plan and health and safety plan (HSP)

Personal protection equipment

Sample containers appropriate for the matrix being sampled
Uniquely numbered sample identification labels

One-gallon covered cans half-filled with absorbent packing material, to be used as necessary
to hold waste

Chain-of-custody sheets

Decontamination equipment (Procedure I-F, Equipment Decontamination.)

Glass thieving tubes, composite liquid waste sampler (COLIWASA), or equivalent
Drum-opening devices

Monitoring equipment for the detection of toxic and explosive environments, whenever the
contents are not known

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:

Revision:

Page:

i-D-1
May 2015
3 of 13

5.3.1 Drum-Opening Devices

5.3.1.1	Bung Wrench

A common method for opening drums manually is using a universal bung wrench. The fittings on a
bung wrench are made to remove nearly all commonly encountered bungs. They are usually
constructed of cast iron, brass, or a bronze-beryllium, non-sparking alloy. The use of a non-sparking
wrench does not eliminate the possibility of producing a spark.

5.3.1.2	Drum Deheader

One means by which a drum can be opened manually when a bung is not removable with a bung
wrench is by using a drum deheader. This tool is constructed of forged steel with an alloy steel blade
and is designed to partially or completely cut off the lid of a drum by means of scissors-like cutting
action. A limitation of this device is that it can be attached only to closed head drums. Drums with
removable heads or over-pressurized drums should be opened by other means.

5.3.1.3	Backhoe Spike

The most common means of opening drums remotely for sampling is the use of a metal spike
attached or welded to a backhoe bucket. In addition to being very efficient, this method can greatly
reduce the likelihood of personnel exposure.

5.3.1.4	Hydraulic Drum Opener

Hydraulic drum openers use hydraulic pressure to pierce the drum. It consists of a manually operated
pump that pressurizes oil through a length of hydraulic line attached to a metal point that pierces the
side or head of the drum.

5.3.1.5	Pneumatic Devices

A pneumatic bung remover consists of a compressed air supply that is controlled by a heavy-duty,
two-stage regulator. A high-pressure air line of desired length delivers compressed air to a pneumatic
drill, which is adapted to turn a bung fitting selected to fit the bung to be removed. An adjustable
bracketing system positions and aligns the pneumatic drill over the bung. The bracketing system
must be attached to the drum before the drill can be operated. Once the bung has been loosened, the
bracketing system must be removed before the drum can be sampled. The pneumatic bung opener
does not permit the slow venting of the container, and therefore, appropriate precautions must be
taken. The pneumatic bung opener also requires the container to be upright and relatively level. This
device cannot remove bungs that are rusted shut.

5.4 Sampling Procedure
5.4.1 Drum Staging

Prior to sampling, stage the drums (if not already staged) for easy access. Ideally, the staging area
should be located just far enough from the drum opening area to prevent a chain reaction if one drum
with unknown contents or visibly over-pressurized should explode or catch fire when opened.

During staging, physically separate the drums into the following categories: those containing liquids;
those containing solids; lab packs; gas cylinders; and those that are empty. The strategy for sampling
and handling drum/containers in each of these categories will be different. Categories are determined

by:

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:	i-D-1

Revision:	May 2015

Page:	4 of 13

Visual inspection of the drum and its labels, codes, etc. Solids and sludges are typically
disposed of in open top drums. Closed head drums with a bung opening generally contain
liquid.

Visual inspection of the contents of the drum during sampling, followed by restaging, if
needed.

For discovered drums that require excavation, eliminate immediate hazards by over packing or
transferring the drum's contents to another suitable container, affixing with a numbered tag, and
transferring to a staging area. Use color-coded tags, labels, or bands to mark similar waste types.
Record a description of each drum, its condition, any unusual markings, and the location where it
was buried or stored on a drum data sheet (see Attachment I-D-1-1.) This data sheet becomes the
principal record-keeping tool for tracking the drum on site.

Where space allows, physically separate the unknown or suspected hazardous waste-containing or
over-pressurized drum opening area from the drum removal and drum staging operations. Move
drums from the staging area to the drum opening area one at a time using forklift trucks equipped
with drum grabbers or a barrel grappler. In a large-scale drum handling operation, drums may be
conveyed to the drum opening area using a roller conveyor.

5.4.2 Drum Opening

There are three techniques for opening drums at suspected or known hazardous waste sites:

Manual opening with non-sparking bung wrenches
Drum deheading

Remote drum puncturing and bung removal

The choice of drum opening technique and accessories depends on the number of drums to be
opened, their waste contents, and their physical condition. Remote drum opening equipment should
always be considered to protect worker safety. Under Occupational Safety and Health
Administration 1910.120 (OSHA 1998), manual drum opening with bung wrenches or deheaders
should be performed only on structurally sound drums whose waste contents are known not to be
shock sensitive, reactive, explosive, or flammable.

5.4.2.1 Manual Drum Opening
Bung Wrench

Do not perform manual drum opening with bung wrenches unless the drums are structurally sound
(no evidence of bulging or deformation) and their contents are known to be non-explosive. If
opening the drum with bung wrenches is deemed reasonably cost-effective and safe, then certain
procedures should be implemented to minimize the hazard:

Field personnel should be fully outfitted with protective gear.

Continually monitor atmospheres for toxicity, explosivity, and if applicable, radioactivity.

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:

Revision:

Page:

i-D-1
May 2015
5 of 13

Position drums upright with the bung up, or, for drums with bungs on the side, laid on their
sides with the bung plugs up.

The wrenching motion should be a slow, steady pull across the drum. If the length of the
bung wrench handle provides inadequate leverage for unscrewing the plug, attach a "cheater
bar" to the handle to improve leverage.

5.4.2.2	Drum Deheading

Do not perform drum deheading unless the drums are structurally sound (no evidence of bulging or
deformation) and their contents are known to be non-explosive. Drums are opened with a drum
deheader by first positioning the cutting edge just inside the top chime and then tightening the
adjustment screw so that the deheader is held against the side of the drum. Moving the handle of the
deheader up and down while sliding the deheader along the chime will enable the entire top to be
rapidly cut off, if desired. If the top chime of a drum has been damaged or badly dented, it may not
be possible to cut the entire top off. Because there is always the possibility that a drum may be under
pressure, make the initial cut very slowly to allow for the gradual release of any built-up pressure. A
safer technique would be to employ a remote method prior to using the deheader.

Self-propelled drum openers, which are either electrically or pneumatically driven, are available and
can be used for quicker and more efficient deheading.

5.4.2.3	Remo te Opening

Remotely operated drum opening tools are the safest available means of opening a drum. Remote
drum opening is slow, but provides a high degree of safety compared to manual methods of opening.

Backhoe Spike

"Stage" or place drums in rows with adequate aisle space to allow ease in backhoe maneuvering.
Once staged, punching a hole in the drumhead or lid with the spike can quickly open the drums.

Decontaminate the spike after each drum is opened to prevent cross contamination. Even though
some splash or spray may occur when this method is used, mounting a large shatter-resistant shield
in front of the operator's cage can protect the operator of the backhoe. When combined with the
normal personal protection gear, this practice should protect the operator. Providing the operator
with an on-board air line system affords additional respiratory protection.

Hydraulic Devices

Hydraulic devices consist of a piercing device with a metal point that is attached to the end of a
hydraulic line and is pushed into the drum by hydraulic pressure. The piercing device can be attached
so that a hole for sampling can be made in either the side or the head of the drum. Some of the metal
piercing devices are hollow or tube-like so that they can be left in place, if desired, to serve as a
permanent tap or sampling port. The piercing device is designed to establish a tight seal after
penetrating the container.

Pneumatic Devices

Pneumatically operated devices using compressed air have been designed to remove drum bungs
remotely.

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:

Revision:

Page:

i-D-1
May 2015
6 of 13

5.4.3 Drum Sampling

Immediately after the drum has been opened, sample the headspace gases within the drum using an
explosimeter, organic vapor analyzer, and/or a photoionization detector, and record the data on the
Drum Data Sheet (see Attachment I-D-l-1) as necessary. The CTO WP shall reference procedures
listed in the site HSP.

In most cases, it is impossible to observe the contents of these sealed or partially sealed drums.
Because some layering or stratification is likely in any solution left undisturbed over time, take a
sample that represents the entire depth of the vessel. In addition, a sample of solid material collected
from a drum should include the entire depth to be most representative of the drum contents.

When sampling a previously sealed drum, check for the presence of bottom sludge. This is easily
accomplished by measuring the depth to apparent bottom, and then comparing it to the known
interior depth.

5.4.3.1 Gla ss Thief Sampler

The most widely used implement for sampling liquids in a drum is a glass tube (glass thief,
6 millimeters inner diameter x 30.47 centimeters [cm] [48 inches] length). This tool is simple, cost
effective, quick, and collects a sample without having to decontaminate.

Specific Sampling Procedure Using a Glass Thief

1.	Remove the cover from the sample container.

2.	Slowly insert the glass tubing almost to the bottom of the drum or until a solid layer is
encountered. About 1 foot of tubing should extend above the drum.

3.	Allow the waste in the drum to reach its natural level in the tube.

4.	Cap the top of the sampling tube with a tapered stopper or thumb, ensuring liquid does not
come into contact with the stopper.

5.	Carefully remove the capped tube from the drum, and insert the uncapped end into the
sample container. Do not spill liquid on the outside of the sample container.

6.	Release the stopper, and allow the glass thief to drain completely into the sample container.
Fill the container to about 2/3 of capacity.

7.	Remove the tube from the sample container, carefully break it into pieces, and place the
pieces in the drum.

8.	Cap the sample container tightly, and place the pre-labeled sample container in a carrier.

9.	Replace the bung or place plastic over the drum.

10.	Transport the sample to the decontamination zone to be prepared for transport to the
analytical laboratory.

In many instances, a drum containing waste material will have a sludge layer on the bottom. Slow
insertion of the sampling tube down into this layer and then a gradual withdrawal will allow the
sludge to act as a bottom plug to maintain the fluid in the tube. The plug can be gently removed and
placed into the sample container by the use of a stainless steel lab spoon.

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:

Revision:

Page:

i-D-1
May 2015
7 of 13

In some instances, disposal of the tube by breaking it into the drum might interfere with eventual
plans for the removal of its contents. Clear this technique with NAVFAC Pacific personnel or
evaluate other disposal techniques.

5.4.3.2 COUWASA SAMPLER

The COLIWASA is a much-cited sampler designed to permit representative sampling of multiphase
wastes from drums and other containerized wastes. It collects a sample from the full depth of a drum
and maintains it in the transfer tube until delivery to the sample bottle. One configuration consists of
a 152 cm by 4 cm-inner diameter section of tubing with a neoprene stopper at one end attached by a
rod running the length of the tube to a locking mechanism at the other end. Manipulation of the
locking mechanism opens and closes the sampler by raising and lowering the neoprene stopper.

The major drawbacks associated with using a COLIWASA include decontamination and cost. The
sampler is difficult (if not impossible) to decontaminate in the field, and its high cost relative to
alternative procedures (glass tubes) make it an impractical throwaway item. However, disposable,
high-density, inert polyethylene COLIWASAs are available at a nominal cost. Although the
applications of a disposable COLIWASA are limited, it is especially effective in instances where a
true representation of a multiphase waste is absolutely necessary.

Procedures for Use

1.	Open the sampler by placing the stopper rod handle in the T-position and pushing the rod
down until the handle sits against the sampler's locking block.

2.	Slowly lower the sampler into the liquid waste. Lower the sampler at a rate that permits the
levels of the liquid inside and outside the sampler tube to be about the same. If the level of
the liquid in the sample tube is lower than that outside the sampler, the sampling rate is too
fast and will result in a non-representative sample.

3.	When the sampler stopper hits the bottom of the waste container, push the sampler tube
downward against the stopper to close the sampler. Lock the sampler in the closed position
by turning the T-handle until it is upright and one end rests tightly on the locking block.

4.	Slowly withdraw the sampler from the waste container with one hand while wiping the
sampler tube with a disposable cloth or rag with the other hand.

5.	Carefully discharge the sample into a suitable sample container by slowly pulling the lower
end of the T-handle away from the locking block while the lower end of the sampler is
positioned in a sample container.

6.	Cap the sample container with a Teflon-lined cap, attach a label and seal, and record it on the
sample data sheet.

7.	Unscrew the T-handle of the sampler, and disengage the locking block.

8.	Clean the sampler.

5.5 Drum Closing

Upon completion of sampling activities, close the drums, and then store them in a secure area as
described in Procedure I-A-6, Investigation-Derived Waste Management. If the bung opening and
the bung are still intact, then close the drum by replacing the bung. In addition, open top drums that

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:

Revision:

Page:

i-D-1
May 2015
8 of 13

are still in good condition can be closed by replacing the top and securing the drum ring with the
attached bolt.

If a drum cannot be closed in the manner discussed above, then secure it by placing it in an approved
85-gallon overpack drum (type UN l A2/Y43/S). Fill the void spaces between the outer portion of the
inner drum and the inside of the overpack drum with vermiculite to secure the drum contents to the
extent possible.

5.6	Equipment Decontamination

Decontamination of sampling equipment should follow Procedure I-F, Equipment Decontamination.

5.7	Sample Preservation, Containers, Handling, and Storage

1. Do not add preservatives to the sample unless specifically required by the analytical method

2.	Place the labeled sample container in two re-sealable plastic bags.

3.	If the contents of the investigation-derived waste drum are unknown, or known to contain
hazardous waste, place each bagged sample container in a 1-gallon covered can containing
absorbent packing material. Place the lid on the can.

4.	Mark the sample identification number on the outside of the can.

5.	Place the samples in a cooler, and fill the remaining space with absorbent packing material.

6.	Fill out the chain-of-custody record for each cooler, place it in a re-sealable plastic bag, and
affix it to the inside lid of the cooler.

7.	Secure the lid of the cooler, and affix the custody seal.

9. Arrange for the appropriate transport mode consistent with the type of waste involved
(hazardous or non-hazardous).

6.	Records

Keep records of all sampling activities in the field notebook and on the Drum Data Sheets.
Document sample custody on the chain-of-custody form. The CTO Manager shall review these
documents at the completion of field activities, and, at least on a monthly basis for long-term
projects.

7.	Health and Safety

Field Personnel shall perform work in accordance with the current (or as contractually obligated)
United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2008) and site-specific health and safety plan.

8.	References

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

or WP.

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:

Revision:

Page:

i-D-1
May 2015
9 of 13

Occupational Safety and Health Administration (OSHA). 1998. Occupational Safety and Health
Standards (29 CFR 1910); with special attention to Section 1910.120, Hazardous Waste Operations
and Emergency Response (HAZWOPER). Washington, DC: United States Department of Labor.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-A-6, Investigation-Derived Waste Management.

Procedure I-F, Equipment Decontamination.

9. Attachments

Attachment I-D-l-1: Drum Data Sheet

-------
This page intentionally left blank

-------
Attachment l-D-1-1
Drum Data Sheet

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Drum Sampling

Procedure Number:

Revision:

Page:

i-D-1
May 2015
13 of 13

DRUM DATASHEET

CTO/DO #:	Date

Sampled:

Drum I.D.#:	Time:

Estimated Liquid Quantity:
Original Drum Location:
Staging Location:
Sampler's Name:

Drum Condition:

Physical Appearance of the Drum/Bulk Contents:
Headspace Gas Concentration:

Odor:	Color:

pH:	% Liquid:

Laboratory	Date of Analysis:

Analytical Data:

Compatibility:

Hazard:

Waste I.D.:

Treatment Disposal Recommendations:

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program

Procedure Number:

l-E

Soil and Rock Classification

Revision:

May 2015



Page:

1 of 19

Soil and Rock Classification

1.	Purpose

This section sets forth standard operating procedures for soil and rock classification for use by
United States Navy Environmental Restoration (ER) Program, Naval Facilities Engineering
Command (NAVFAC), Pacific personnel.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the Uniform Federal Policy-Quality Assurance Project Plan
(DoD 2005). As professional guidance for specific activities, this procedure is not intended to
obviate the need for professional judgment during unforeseen circumstances. Deviations from this
procedure while planning or executing planned activities must be approved and documented by the
following prime contractor representatives: the CTO Manager and the Quality Assurance (QA)
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

3.	Definitions

None.

4.	Responsibilities

The prime contractor CTO Manager is responsible for ensuring that these standard soil and rock
classification procedures are followed during projects conducted under the ER Program and that a
qualified individual conducts or supervises the projects. A qualified individual is defined as a person
with a degree in geology, hydrogeology, soil science, or geotechnical/civil engineering with at least 1
year of experience classifying soil. Supervision is defined as onsite and continuous monitoring of the
individual conducting soil classification. The CTO Manager is responsible for ensuring that all
personnel involved in soil and rock classification have the appropriate education, experience, and
training to perform their assigned tasks as specified in Chief of Naval Operations Instruction 5090.1,
under Specific Training Requirements (DON 2014).

The CTO Manager is responsible for reviewing copies of the field boring log forms on a monthly
basis at a minimum. However, it is recommended that initially boring logs are reviewed daily to
ensure accuracy.

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The Field Manager is responsible for field oversight to ensure that all project field staff follow these
procedures.

Field personnel are responsible for the implementation of this procedure.

-------
NAVFAC Pacific ER Program

Procedure Number:

Revision:

Page:

i-E

May 2015
2 of 19

Soil and Rock Classification

5. Procedures

5.1 Soil Classification

The basic purpose of the classification of soil is to thoroughly describe the physical characteristics of
the sample and to classify it according to an appropriate soil classification system for the NAVFAC
Pacific ER Program. The Unified Soil Classification System (USCS) was developed so that soils
could be described on a common basis by different investigators and serve as a "shorthand"
description of soil. A classification of a soil in accordance with the USCS includes not only a group
symbol and name, but also a complete word description.

Describing soil on a common basis is essential so that soil described by different site qualified
personnel is comparable. Site individuals describing soil as part of site activities must use the
classification system described herein to provide the most useful geologic database for all present
and future subsurface investigations and remedial activities at NAVFAC Pacific ER Program sites.

The site geologist or other qualified individual shall describe the soil and record the description in a
boring log or logbook. The essential items in any written soil description are as follows:

Classification group name (e.g., silty sand)

Color, moisture, and odor
Range of particle sizes

Approximate percentage of boulders, cobbles, gravel, sand, and fines
Plasticity characteristics of the fines

In-place conditions, such as density/consistency, compaction, amount of
induration/cementation or weathering, retention of the parent rock fabric, and structure

USCS classification symbol

The USCS serves as "shorthand" for classifying soil into 15 basic groups:

GW1	Well graded (poorly sorted) gravel (>50 percent gravel, <5percent fines)

GP1	Poorly graded (well sorted) gravel (>50percent gravel, <5percent fines)

GM1	Silty gravel (>50 percent gravel, >15 percent silt)

GC1	Clayey gravel (>50 percent gravel, >15 percent clay)

SW1	Well graded (poorly sorted) sand (>50 percent sand, <5 percent fines)

SP1	Poorly graded (well sorted) sand (>50 percent sand, <5 percent fines)

SM1	Silty sand (>50 percent sand, >15 percent silt)

SC1	Clayey sand (>50 percent sand, >15 percent clay)

1 If percentage of fine is 5 percent to 15 percent, a dual identification shall be given (e.g., a soil with more than
50 percent poorly sorted gravel and 10 percent clay is designated GW-GC.

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
3 of 19

ML2 Inorganic, low plasticity silt (slow to rapid dilatancy, low toughness, and plasticity)

CL2	Inorganic, low plasticity (lean) clay (no or slow dilatancy, medium toughness and
plasticity)

MH2	Inorganic elastic silt (no to slow dilatancy, low to medium toughness and plasticity)

CH2	Inorganic, high plasticity (fat) clay (no dilatancy, high toughness, and plasticity)

OL	Organic low plasticity silt or organic silty clay

OH	Organic high plasticity clay or silt

PT	Peat and other highly organic soil

Figure I-E-l defines the terminology of the USCS. Flow charts presented in Figure I-E-2 and
Figure I-E-3 indicate the process for describing soil. The particle size distribution and the plasticity
of the fines are the two properties of soil used for classification. In some cases, it may be appropriate
to use a borderline classification (e.g., SC/CL) if the soil has been identified as having properties that
do not distinctly place the soil into one group.

5.1.1 Estimation of Particle Size Distribution

One of the most important factors in classifying a soil is the estimated percentage of soil constituents
in each particle size range. Being proficient in estimating this factor requires extensive practice and
frequent checking. The steps involved in determining particle size distribution are listed below:

1.	Select a representative sample (approximately 1/2 of a 6-inch long by 2.5-inch diameter
sample liner).

2.	Remove all particles larger than 3 inches from the sample. Estimate and record the percent
by volume of these particles. Only the fraction of the sample smaller than 3 inches is
classified.

3.	Estimate and record the percentage of dry mass of gravel (less than 3 inches and greater than
1/4 inch).

4.	Considering the rest of the sample, estimate, and record the percentage of dry mass of sand
particles (about the smallest particle visible to the unaided eye).

5.	Estimate and record the percentage of dry mass of fines in the sample (do not attempt to
separate silts from clays).

6.	Estimate percentages to the nearest 5 percent. If one of the components is present in a
quantity considered less than 5 percent, indicate its presence by the term "trace."

7.	The percentages of gravel, sand, and fines must add up to 100 percent. "Trace" is not
included in the 100 percent total.

2 If the soil is estimated to have 15 percent to 25 percent sand or gravel, or both, the words "with sand" or
"with gravel" (whichever predominates) shall be added to the group name (e.g., clay with sand, CL; or silt with
gravel, ML). If the soil is estimated to have 30 percent or more sand or gravel, or both, the words "sandy" or
"gravely" (whichever predominates) shall be added to the group name (e.g., sandy clay, CL). If the percentage
of sand is equal to the percent gravel, use "sandy."

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
4 of 19

5.1.2 Soil Dilatancy, Toughness, and Plasticity

5.1.2.1 Dilatancy

To evaluate dilatancy, follow these procedures:

1.	From the specimen, select enough material to mold into a ball about 1/2 inch (12 millimeters
[mm]) in diameter. Mold the material, adding water if necessary, until it has a soft, but not
sticky, consistency.

2.	Smooth the soil ball in the palm of one hand with the blade of a knife or small spatula. Shake
horizontally, striking the side of the hand vigorously against the other hand several times.
Note the reaction of water appearing on the surface of the soil. Squeeze the sample by
closing the hand or pinching the soil between the fingers, and note the reaction as none,
slow, or rapid in accordance with the criteria in Table I-E-l. The reaction is the speed with
which water appears while shaking, and disappears while squeezing.

Table l-E-1: Criteria for Describing Dilatancy

Description

Criteria

None

No visible change in specimen.

Slow

Water appears slowly on the surface of the specimen during shaking and does not disappear or disappears
slowly upon squeezing.

Rapid

Water appears quickly on the surface of the specimen during shaking and disappears quickly upon squeezing.

5.1.2.2 Toughness

Following the completion of the dilatancy test, shape the test specimen into an elongated pat and roll
it by hand on a smooth surface or between the palms into a thread about 1/8 inch (3 mm) in diameter.
(If the sample is too wet to roll easily, spread it into a thin layer and allow it to lose some water by
evaporation.) Fold the sample threads and re-roll repeatedly until the thread crumbles at a diameter
of about 1/8 inch. The thread will crumble at a diameter of 1/8 inch when the soil is near the plastic
limit. Note the pressure required to roll the thread near the plastic limit. Also, note the strength of the
thread. After the thread crumbles, lump the pieces together and knead it until the lump crumbles.
Note the toughness of the material during kneading. Describe the toughness of the thread and lump
as low, medium, or high in accordance with the criteria in Table I-E-2.

Table l-E-2: Criteria for Describing Toughness

Description

Criteria

Low

Only slight pressure is required to roll the thread near the plastic limit. The thread and the lump are weak and
soft.

Medium

Medium pressure is required to roll the thread near the plastic limit. The thread and the lump have medium
stiffness.

High

Considerable pressure is required to roll the thread near the plastic limit. The thread and the lump have very high
stiffness.

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
5 of 19

DEFINITION OF TERMS

MAJOR DIVISIONS SYMBOLS TYPICAL DESCRIPTIONS

COARSE GRAINED SOILS

More Than Half of Material
Is Larger Than No. 200
Sieve Size

GRAVELS

More Than
Half of
Coarse
Fraction is
Smaller Than
No. 4 Sieve

CLEAN •«
GRAVELS * *

GW

*

Well graded gravels, gravel-sand mixtures, little or no fines

(Less tnan
6% Fines) ^ 0

\ GP

Poorly graded gravels, gravel-sand mixtures, little or no fines

h

GRAVELS : h

«I GM

Silty gravels, gravel-sand-silt mixtures, non-plastic fines

witn hines '/V,

GC

Clayey gravels, gravel-sand-clay mixtures, plastic fines

SANDS

More Than
Half of
Coarse
Fraction is
Smaller Than
No. 4 Sieve

CLEAN

sands •:

?> sw

Well graded sands, gravelly sands, little or no fines

(Less tnan T
6% Fines) V

sp

Poorly graded sands, gravelly sands, little or no fines

SANnfi

SM

Silty sands, sand-silt mixtures, non-plastic fines

With Fines *

/ /

// sc

Clayey sands, sand-clay mixtures, plastic fines

FINE GRAINED SOILS

More Than Half of Material
is Smaller Than No. 200
Sieve Size

SILTS AN

Liquid
Less Th



ML

Inorganic silts, rock flour, fine sandy silts or clays, and clayey silts
with non- or slightly-plastic fines

L) CLAYS ^

Limit is

CL

Inorganic clays ot low to medium plasticity, gravelly clays, silty clays,
sandy clays, lean clays



OL

Organic silts and organic silty clays of low plasticity

SILTS Ah

Liquid
Greater'



W: MH

Inorganic silts, micaceous or diatomaceous fine sandy or silty soils,
elastic silts, clayey silt

Limit is ' /

// CH

inorganic clays of high plasticity, fat clays



| OH

Organic clays of medium to high plasticity, organic silts

HIGHLY ORGANIC SOILS s

— PT

Peat and other highly organic soils

GRAIN SIZES

SILTS AND CLAYS

SAND

GRAVEL

COBBLES

BOULDERS

FINE

MEDIUM

COARSE

FINE COARSE

200 40 10

4

3/4" 3" 12'



U.S. STANDARD SERIES SIEVE



CLEAR SQUARE SIEVE OPENINGS

Figure l-E-1: Unclassified Soil Classification System (USCS)

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
7 of 19

LLI

CL
3

o

0£
O

_	D)

E	>	^

to	2	>» >»

(/>	o)	to to
o o

5	5	c c

_to _to	_to	jd jd

o o	o	>,>,

C C	C	"O T3

TO TO	TO	C C

a) a)	a)	to to

	l 	I 	I	CO CO

A	A

0) 0)
> >
TO TO

>. >.
TO TO
O O

Id	Id

>	>

TO	TO

o	o

-Q -Q	O) D) (f)	(7)

C C	vP -nP	-nP	vP

to to	o®* o®*	o®*	8®*

(/)(/)	LO LO	LO	LO

^ ^	V A|	V	A|

ra

? 5 £= £=

TO	(A (A

f f >- >-

(/) O)	_	_

"5	"5	r	>r

 >
TO TO

O O	

c.

AI V 2 2 ra

-Q -Q O) O)  ^
2 >*>*

(/) Q) _ro

o o

5 5

TO

TO

O

>.>•.>•.	««-««-	_>»

TO TO	TO	>, >,	"H3

o o	o	"o "a	>

•4—1 -1—'	-1—'	jj; jj;	TO

TO TO	TO	TO TO	'r

Ll_ Ll_	Ll_	(f) (f)	O
* *

0) 0)
> >
TO TO

O O	

> >	T3 T3

ai v	2 2	ra S

"O "0	O) D)	

" Q) ' ' o
O O to

(/)

 >
TO TO

O O

O

* *

g SJ -a	-a

zm v 2 2 S	ra

¦0-0 O) D) (/)	(/)

C C ..p ..p ..p	vP

to to ©^ ©^ ©^	©^

(/)(/) LO LO LO	LO

O
m

>-
-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
9 of 19

Figure l-E-3: Flow Chart for Soil with

Gravel

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
11 of 19

5.1.2.3 Plasticity

The plasticity of a soil is defined by the ability of the soil to deform without cracking, the range of
moisture content over which the soil remains in a plastic state, and the degree of cohesiveness at the
plastic limit. The plasticity characteristic of clays and other cohesive materials is defined by the
liquid limit and plastic limit. The liquid limit is defined as the soil moisture content at which soil
passes from the liquid to the plastic state as moisture is removed. The test for the liquid limit is a
laboratory, not a field, analysis.

The plastic limit is the soil moisture content at which a soil passes from the plastic to the semi-solid
state as moisture is removed. The plastic limit test can be performed in the field and is indicated by
the ability to roll a 1/8-inch (0.125-inch) diameter thread of fines, the time required to roll the thread,
and the number of times the thread can be re-rolled when approaching the plastic limit.

The plasticity tests are not based on natural soil moisture content, but on soil that has been
thoroughly mixed with water. If a soil sample is too dry in the field, add water prior to performing
classification. If a soil sample is too sticky, spread the sample thin and allow it to lose some soil
moisture.

Table I-E-3 presents the criteria for describing plasticity in the field using the rolled thread method.

Table l-E-3: Criteria for Describing Plasticity

Description

Criteria

Non-Plastic

A 1/8-inch thread cannot be rolled.

Low Plasticity

The thread can barely be rolled.

Medium Plasticity

The thread is easy to roll and not much time is required to reach the plastic limit.

High Plasticity

It takes considerable time rolling the thread to reach the plastic limit.

5.1.3	Angularity

The following criteria describe the angularity of the coarse sand and gravel particles:

Rounded particles have smoothly-curved sides and no edges.

Subrounded particles have nearly plane sides, but have well-rounded corners and edges.

Subangular particles are similar to angular, but have somewhat rounded or smooth
edgesand.

Angular particles have sharp edges and relatively plane sides with unpolished surfaces.
Freshly broken or crushed rock would be described as angular.

5.1.4	Color, Moisture, and Odor

The natural moisture content of soil is very important. Table I-E-4 shows the terms for describing the
moisture condition and the criteria for each.

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
12 of 19

Table l-E-4: Soil Moisture Content Qualifiers

Qualifier

Criteria

Dry

Absence of moisture, dry to the touch

Moist

Damp but no visible water

Wet

Visible water, usually soil is below water table

Color is described by hue and chroma using the Munsell Soil Color Chart (Munsell 2000). For
uniformity, all site geologists shall use this chart for soil classification. Doing so will facilitate
correlation of geologic units between boreholes logged by different geologists The Munsell Color
Chart is a small booklet of numbered color chips with names like "5YR 5/6, yellowish-red." Note
mottling or banding of colors. It is particularly important to note and describe staining because it
may indicate contamination.

In general, wear a respirator if strong organic odors are present. If odors are noted, describe them if
they are unusual or suspected to result from contamination. An organic odor may have the distinctive
smell of decaying vegetation. Unusual odors may be related to hydrocarbons, solvents, or other
chemicals in the subsurface. An organic vapor analyzer may be used to detect the presence of
volatile organic contaminants.

5.1.5 In-Place Conditions

Describe the conditions of undisturbed soil samples in terms of their density/consistency
(i.e., compactness), cementation, and structure utilizing the following guidelines:

5.1.5.1 Density/Consistency

Density and consistency describe a physical property that reflects the relative resistance of a soil to
penetration. The term "density" is commonly applied to coarse to medium-grained sediments
(i.e., gravels, sands), whereas the term "consistency" is normally applied to fine-grained sediments
(i.e., silts, clays). There are separate standards of measure for both density and consistency that are
used to describe the properties of a soil.

The density or consistency of a soil is determined by observing the number of blows required to
drive a 1 3/8-inch (35 mm) diameter split barrel sampler 18 inches using a drive hammer weighing
140 pounds (63.5 kilograms) dropped over a distance of 30 inches (0.76 meters). Record the number
of blows required to penetrate each 6 inches of soil in the field boring log during sampling. The first
6 inches of penetration is considered to be a seating drive; therefore, the blow count associated with
this seating drive is recorded, but not used in determining the soil density/consistency. The sum of
the number of blows required for the second and third 6 inches of penetration is termed the "standard
penetration resistance," or the "N-value." The observed number of blow counts must be corrected by
an appropriate factor if a different type of sampling device (e.g., Modified California Sampler with
liners) is used. For a 2 3/8-inch inner diameter Modified California Sampler equipped with brass or
stainless steel liners and penetrating a cohesionless soil (sand/gravel), the N-value from the Modified
California Sampler must be divided by 1.43 to provide data that can be compared to the 1 3/8-inch
diameter sampler data.

For a cohesive soil (silt/clay), the N-value for the Modified California Sampler should be divided by
a factor of 1.13 for comparison with 1 3/8-inch diameter sampler data.

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
13 of 19

Drive the sampler and record blow counts for each 6-inch increment of penetration until one of the
following occurs:

A total of 50 blows have been applied during any one of the three 6-inch increments; a
50-blow count occurrence shall be termed "refusal" and noted as such on the boring log.

A total of 150 blows have been applied.

The sampler is advanced the complete 18 inches without the limiting blow counts occurring,
as described above.

If the sampler is driven less than 18 inches, record the number of blows per partial increment on the
boring log. If refusal occurs during the first 6 inches of penetration, the number of blows will
represent the N-value for this sampling interval. Table I-E-5 and Table I-E-6 present representative
descriptions of soil density/consistency vs. N-values.

Table l-E-5: Measuring Soil Density with a California Sample - Relative Density (Sands, Gravels)



Field Criteria (N-Value)

Description

1 3/8 in. ID Sampler

2 in. ID Sampler using 1.43 factor

Very Loose

0—4

0-6

Loose

4-10

6-14

Medium Dense

10-30

14—43

Dense

30-50

43-71

Very Dense

>50

>71

Table l-E-6: Measuring Soil Density with a California Sampler - Fine Grained Cohesive Soil



Field Criteria (N-Value)

Description

1 3/8 in. ID Sampler

2 in. ID Sampler using 1.13 factor

Very Soft

0-2

0-2

Soft

2—4

2-4

Medium Stiff

4-8

4-9

Stiff

8-16

9-18

Very Stiff

16-32

18-36

Hard

>32

>36

For undisturbed fine-grained soil samples, it is also possible to measure consistency with a hand-held
penetrometer. The measurement is made by placing the tip of the penetrometer against the surface of
the soil contained within the sampling liner or shelby tube, pushing the penetrometer into the soil a
distance specified by the penetrometer manufacturer, and recording the pressure resistance reading in
pounds per square foot. The values are as follows (Table I-E-7):

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
14 of 19

Table l-E-7: Measuring Soil Consistency with a Hand-Held Penetrometer

Description

Pocket Penetrometer Reading (psf)

Very Soft

0-250

Soft

250-500

Medium Stiff

500-1,000

Stiff

1,000-2,000

Very Stiff

2,000-4,000

Hard

>4,000

Consistency can also be estimated using thumb pressure using Table I-E-8.

Table l-E-8: Measuring Soil Consistency Using Thumb Pressure

Description

Criteria

Very Soft

Thumb will penetrate soil more than 1 inch (25 mm)

Soft

Thumb will penetrate soil about 1 inch (25 mm)

Firm

Thumb will penetrate soil about 1/4 inch (6 mm)

Hard

Thumb will not indent soil but readily indented with thumbnail

Very Hard

Thumbnail will not indent soil

5.1.5.2 Cement a tion

Cementation is used to describe the friability of a soil. Cements are chemical precipitates that
provide important information as to conditions that prevailed at the time of deposition, or conversely,
diagenetic effects that occurred following deposition. Seven types of chemical cements are
recognized by Folk (1980). They are as follows:

1.	Quartz - siliceous

2.	Chert - chert-cemented or chalcedonic

3.	Opal - opaline

4.	Carbonate - calcitic, dolomitic, sideritic (if in doubt, calcareous should be used)

5.	Iron oxides - hematitic, limonitic (if in doubt, ferruginous should be used)

6.	Clay minerals - if the clay minerals are detrital or have formed by recrystallization of a
previous clay matrix, they are not considered to be a cement. Only if they are chemical
precipitates, filling previous pore space (usually in the form of accordion-like stacks or
fringing radial crusts) should they be included as "kaolin-cemented," "chlorite-cemented,"
etc.

7.	Miscellaneous minerals - pyritic, collophane-cemented, glauconite-cemented, gypsiferous,
anhydrite-cemented, baritic, feldspar-cemented, etc.

The degree of cementation of a soil is determined qualitatively by utilizing finger pressure on the soil
in one of the sample liners to disrupt the gross soil fabric. The three cementation descriptors are as
follows:

-------
NAVFAC Pacific ER Program

Procedure Number:

Revision:

Page:

i-E

May 2015
15 of 19

Soil and Rock Classification

1.	Weak - friable; crumbles or breaks with handling or slight finger pressure

2.	Moderate - friable; crumbles or breaks with considerable finger pressure

3.	Strong - not friable; will not crumble or break with finger pressure

5.1.5.3	Structure

This variable is used to qualitatively describe physical characteristics of soil that are important to
incorporate into hydrogeological and/or geotechnical descriptions of soil at a site. Appropriate soil
structure descriptors are as follows:

Granular: Spherically shaped aggregates with faces that do not accommodate adjoining
faces

Stratified: Alternating layers of varying material or color with layers at least 6 mm (1/4 inch)
thick; note thickness

Laminated: Alternating layers of varying material or color with layers less than 6 mm
(1/4 inch) thick; note thickness

Blocky: Cohesive soil that can be broken down into small angular or subangular lumps that
resist further breakdown

Lensed: Inclusion of a small pocket of different soil, such as small lenses of sand, should be
described as homogeneous if it is not stratified, laminated, fissured, or blocky. If lenses of
different soil are present, the soil being described can be termed homogeneous if the
description of the lenses is included

Prismatic or Columnar: Particles arranged about a vertical line, ped is bounded by planar,
vertical faces that accommodate adjoining faces; prismatic has a flat top; columnar has a
rounded top

Platy: Particles are arranged about a horizontal plane

5.1.5.4	Other Features

Mottled: Soil that appears to consist of material of two or more colors in blotchy distribution

Fissured: Breaks along definite planes of fracture with little resistance to fracturing
(determined by applying moderate pressure to sample using thumb and index finger)

Slickensided: Fracture planes appear polished or glossy, sometimes striated (parallel grooves
or scratches)

5.1.6 Development of Soil Description

Develop standard soil descriptions according to the following examples. There are three principal
categories under which all soil can be classified. They are described below.

5.1.6.1 Coarse-grained Soil

Coarse-grained soil is divided into sands and gravels. A soil is classified as a sand if over 50 percent
of the coarse fraction is "sand-sized." It is classified as a gravel if over 50 percent of the coarse
fraction is composed of "gravel-sized" particles.

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
16 of 19

The written description of a coarse-grained soil shall contain, in order of appearance: Typical name
including the second highest percentage constituent as an adjective, if applicable (underlined); grain
size of coarse fraction; Munsell color and color number; moisture content; relative density; sorting;
angularity; other features, such as stratification (sedimentary structures) and cementation, possible
formational name, primary USCS classification, secondary USCS classification (when necessary),
and approximate percentages of minor constituents (i.e., sand, gravel, shell fragments, rip-up clasts)
in parentheses.

Example: POORLY SORTED SAND WITH SILT, medium- to coarse-grained, light olive
gray, 5Y 6/2, saturated, loose, poorly sorted, subrounded clasts, SW/SM (minor silt
with approximately 20 percent coarse-grained sand-sized shell fragments, and
80 percent medium-grained quartz sand, and 5 percent to 15 percent ML).

5.1.6.2	Fine-grained Soil

Fine-grained soil is further subdivided into clays and silts according to its plasticity. Clays are rather
plastic, while silts have little or no plasticity.

The written description of a fine-grained soil should contain, in order of appearance: Typical name
including the second highest percentage constituent as an adjective, if applicable (underlined);
Munsell color; moisture content; consistency; plasticity; other features, such as stratification,
possible formation name, primary USCS classification, secondary USCS classification (when
necessary), and the percentage of minor constituents in parentheses.

Example: SANDY LEAN CLAY, dusky red, 2.5 YR 3/2, moist, firm, moderately plastic,
thinly laminated, CL (70 percent fines, 30 percent sand, with minor amounts of
disarticulated bivalves [about 5 percent]).

5.1.6.3	Organic Soil

For highly organic soil, describe the types of organic materials present as well as the type of soil
constituents present using the methods described above. Identify the soil as an organic soil, OL/OH,
if the soil contains enough organic particles to influence the soil properties. Organic soil usually has
a dark brown to black color and may have an organic odor. Often, organic soils will change color,
(e.g., from black to brown) when exposed to air. Some organic soils will lighten in color
significantly when air-dried. Organic soils normally will not have a high toughness or plasticity. The
thread for the toughness test will be spongy.

Example: ORGANIC CLAY, black, 2.5Y, 2.5/1, wet, soft, low plasticity, organic odor, OL
(100 percent fines), weak reaction to HC1.

5.2 Rock Classification

The purpose of rock classification is to thoroughly describe the physical and mineralogical
characteristics of a specimen and to classify it according to an established system. The generalized
rock classification system described below was developed for the NAVFAC Pacific ER Program
because, unlike the USCS for soils, there is no universally accepted rock classification system. In
some instances, a more detailed and thorough rock classification system may be appropriate. Any
modifications to this classification system, or the use of an alternate classification system should be
considered during preparation of the site work plan. Both the CTO Manager and the QA Manager or

-------
NAVFAC Pacific ER Program

Procedure Number:

Revision:

Page:

i-E

May 2015
17 of 19

Soil and Rock Classification

Technical Director must approve any modifications to this classification system, or the use of
another classification system.

Describing rock specimens on a common basis is essential so that rocks described by different site
geologists are comparable. Site geologists describing rock specimens as a part of investigative
activities must use the classification system described herein, or if necessary, another more detailed
classification system. Use of a common classification system provides the most useful geologic
database for all present and future subsurface investigations and remedial activities at NAVFAC
Pacific ER Program sites.

A rock classification template has been designated as shown in Figure I-E-4 to provide a more
consistent rock classification between geologists. The template includes the classification of rocks by
origin and mineralogical composition. When classifying rocks, all site geologists shall use this
template.

The site geologist shall describe the rock specimen and record the description in a borehole log or
logbook. The items essential for classification include:

Classification Name (i.e., schist)

Color

Mineralogical composition and percent

Texture/Grain size (i.e., fine-grained, pegmatitic, aphanitic, glassy)

Structure (i.e., foliated, fractured, lenticular)

Rock Quality Designation (sum of all core pieces greater than two times the diameter of the
core divided by the total length of the core run, expressed as a percentage)

Classification symbol (i.e., MF)

Example: Metamorphic foliated schist: Olive gray, 5Y, 3/2, Garnet 25 percent, Quartz
45 percent, Chlorite 15 percent, Tourmaline 15 percent, Fine-grained with Pegmatite
garnet, highly foliated, slightly wavy, MF.

6.	Records

Document soil classification information collected during soil sampling onto the field boring logs,
field trench logs, and into the field notebook. Procedure I-B-l, Soil Sampling presents copies of the
field boring log form. Copies of this information shall be placed in the project files.

7.	Health and Safety

Field Personnel shall perform work in accordance with the current (or as contractually obligated)
United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2008) and site-specific health and safety plan.

-------
NAVFAC Pacific ER Program

Procedure Number:

Revision:

Page:

i-E

May 2015
18 of 19

Soil and Rock Classification

8.	References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/uip_qapp_vl_0305.pdf.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

Folk, Robert L. 1980. Petrology of Sedimentary Rocks. Austin, TX: Hemphill Publishing Company.

Munsell Color Company (Munsell). 2009. Munsell Soil Color Chart, (Revised). Baltimore.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-B-l, Soil Sampling.

9.	Attachments

None.

-------
NAVFAC Pacific ER Program
Soil and Rock Classification

Procedure Number:

Revision:

Page:

l-E

May 2015
19 of 19

DEFINITION OF TERMS

PRIMARY DIVISIONS

SYMBOLS

SECONDARY DIVISIONS

SEDIMENTARY
ROCKS

Clastic Sediments

CONGLOMERATE



CG

Coarse-grained Clastic Sedimentary Rock types
inducing: Conglomerates and Breccias

SANDSTONE



SS

Clastic Sedimentary Rock types including:
Sandstone, Arkose and Greywacke

SHALE



SH

Fine-grained Clastic Sedimentary Rock types
including: Shale, Siltstone, Mudstone and
Claystone

Chemical
Precipitates

CARBONATES

¦VW

t' I ' I ' I

LS

Chemical Precipitates including: Limestone,
Crystalline Limestone, Fossiliferous Limestone
Micrite and Dolomite

EVAPORITES

* * * X
XXX

XXX
X X X X

XXX
A X X X
XXX

EV

Evaporites including: Anhydrite, Gypsum,
Halite, Travertine and Caliche

IGNEOUS
ROCKS



EXTRUSIVE
(Volcanic)

1 r - r A

" V V V

< v < v

> r * h i
V V * V

c v < v

1 r- 1 r> >

IE

Volcanic Rock types including: Basalt, Andesite,
Rhyolite, Volcanic Tuft, and Volcanic Breccia

INTRUSIVE
(Plutonic)

/ \ s \ s

c c r

/ \ s \ /

C \

/ \ S \ /

\' c r

/ \ / \ s

11

Plutonic Rock types including: Granite, Diorite
and Gabbro

METAMORPHIC
ROCKS

FOLIATED

w

MF

Foliated Rock types including: Slate,
Phyllite, Schist and Gneiss

NON-FOLIATED

rxo

m

MN

Non-foliated Rock types including:
Metaconglomerate, Quartzite and Marble

Figure l-E-4: Rock Classification System

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Equipment Decontamination

Procedure Number:

Revision:

Page:

i-F

May 2015
1 of 5

Equipment Decontamination

1.	Purpose

This standard operating procedure describes methods of equipment decontamination for use during
site activities by United States (U.S.) Navy Environmental Restoration (ER) Program, Naval
Facilities Engineering Command (NAVFAC), Pacific personnel.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the Uniform Federal Policy-Quality Assurance Project Plan
(DoD 2005). As professional guidance for specific activities, this procedure is not intended to
obviate the need for professional judgment during unforeseen circumstances. Deviations from this
procedure while planning or executing planned activities must be approved and documented by the
following prime contractor representatives: the CTO Manager and the Quality Assurance (QA)
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

3.	Definitions

None.

4.	Responsibilities

The prime contractor CTO Manager is responsible for identifying instances of non-compliance with
this procedure and ensuring that decontamination activities comply with this procedure. The CTO
Manager is responsible for ensuring that all personnel involved in equipment decontamination have
the appropriate education, experience, and training to perform their assigned tasks as specified in
Chief ofNaval Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The Field Manager is responsible for field oversight to ensure that all project field staff follow these
procedures.

Field personnel are responsible for the implementation of this procedure.

5.	Procedures

Decontamination of equipment used in sampling of various media, groundwater monitoring, and
well drilling and development is necessary to prevent cross-contamination and to maintain the
highest integrity possible in collected samples. Planning a decontamination program requires
consideration of the following factors:

-------
NAVFAC Pacific ER Program
Equipment Decontamination

Procedure Number:

Revision:

Page:

i-F

May 2015
2 of 5

The location where the decontamination procedures will be conducted
The types of equipment requiring decontamination
The frequency of equipment decontamination

The cleaning technique and types of cleaning solutions appropriate for the contaminants of
concern

The method for containing the residual contaminants and wash water from the
decontamination process

The use of a quality control measure to determine the effectiveness of the decontamination
procedure

The following subsection describes standards for decontamination, including the frequency of
decontamination, cleaning solutions and techniques, containment of residual contaminants and
cleaning solutions, and effectiveness.

5.1	Decontamination Area

Select an appropriate location for the decontamination area at a site based on the ability to control
access to the area, the ability to control residual material removed from equipment, the need to store
clean equipment, and the ability to restrict access to the area being investigated. Locate the
decontamination area an adequate distance away and upwind from potential contaminant sources to
avoid contamination of clean equipment.

It is the responsibility of the site safety and health officer (SSHO) to set up the site zones
(i.e., exclusion, transition, and clean) and decontamination areas. Generally, the decontamination
area is located within the transition zone, upwind of intrusive activities, and serves as the washing
area for both personnel and equipment to minimize the spread of contamination into the clean zone.
For equipment, a series of buckets are set up on a visqueen-lined bermed area. Separate spray bottles
containing laboratory-grade isopropyl alcohol (or alternative cleaning solvent as described in the
CTO work plan [WP]) and distilled water are used for final rinsing of equipment. Depending on the
nature of the hazards and the site location, decontamination of heavy equipment, such as augers,
pump drop pipe, and vehicles, may be accomplished using a variety of techniques.

5.2	Types of Equipment

Drilling equipment that must be decontaminated includes drill bits, auger sections, drill-string tools,
drill rods, split barrel samplers, tremie pipes, clamps, hand tools, and steel cable. Decontamination of
monitoring well development and groundwater sampling equipment includes submersible pumps,
bailers, interface probes, water level meters, bladder pumps, airlift pumps, peristaltic pumps, and
lysimeters. Other sampling equipment that requires decontamination includes, but is not limited to,
hand trowels, hand augers, slide hammer samplers, shovels, stainless-steel spoons and bowls, soil
sample liners and caps, wipe sampling templates, composite liquid waste samplers, and dippers.
However, equipment that is shipped pre-packaged from the vendor should not have to be
decontaminated prior to first use. Equipment with a porous surface, such as rope, cloth hoses, and
wooden blocks, cannot be thoroughly decontaminated and shall be properly disposed of after one
use.

-------
NAVFAC Pacific ER Program
Equipment Decontamination

Procedure Number:

Revision:

Page:

i-F

May 2015
3 of 5

5.3	Frequency of Equipment Decontamination

Decontaminate down-hole drilling equipment and equipment used in monitoring well development
and purging prior to initial use and between each borehole or well. Down-hole drilling equipment,
however, may require more frequent cleaning to prevent cross-contamination between vertical zones
within a single borehole. When drilling through a shallow contaminated zone and installing a surface
casing to seal off the contaminated zone, decontaminate the drilling tools prior to drilling deeper.
Initiate groundwater sampling by sampling groundwater from the monitoring well where the least
contamination is suspected. Decontaminate groundwater, surface water, and soil sampling devices
prior to initial use and between collection of each sample to prevent the possible introduction of
contaminants into successive samples.

5.4	Cleaning Solutions and Techniques

Decontamination can be accomplished using a variety of techniques and fluids. The preferred
method of decontaminating major equipment, such as drill bits, augers, drill string, and pump drop-
pipe, is steam cleaning. To steam clean, use a portable, high-pressure steam cleaner equipped with a
pressure hose and fittings. For this method, thoroughly steam wash equipment, and rinse it with
potable tap water to remove particulates and contaminants.

Where appropriate, disposable materials are recommended. A rinse decontamination procedure is
acceptable for equipment, such as bailers, water level meters, new and re-used soil sample liners, and
hand tools. The decontamination procedure shall consist of the following: (l)wash with a non-
phosphate detergent (alconox, liquinox, or other suitable detergent) and potable water solution;
(2) rinse in a bath with potable water; (3) spray with laboratory-grade isopropyl alcohol; (4) rinse in
a bath with deionized or distilled water; and (5) spray with deionized or distilled water. If possible,
disassemble equipment prior to cleaning. Add a second wash at the beginning of the process if
equipment is very soiled.

Decontaminating submersible pumps requires additional effort because internal surfaces become
contaminated during usage. Decontaminate these pumps by washing and rinsing the outside surfaces
using the procedure described for small equipment or by steam cleaning. Decontaminate the internal
surfaces by recirculating fluids through the pump while it is operating. This recirculation may be
done using a relatively long (typically 4 feet) large-diameter pipe (4-inch or greater) equipped with a
bottom cap. Fill the pipe with the decontamination fluids, place the pump within the capped pipe,
and operate the pump while recirculating the fluids back into the pipe. The decontamination
sequence shall include: (1) detergent and potable water; (2) potable water rinse; (3) potable water
rinse; and (4) deionized water rinse. Change the decontamination fluids after each decontamination
cycle.

Solvents other than isopropyl alcohol may be used, depending upon the contaminants involved. For
example, if polychlorinated biphenyls or chlorinated pesticides are contaminants of concern, hexane
may be used as the decontamination solvent. However, if samples are also to be analyzed for volatile
organics, hexane shall not be used. In addition, some decontamination solvents have health effects
that must be considered. Decontamination water shall consist of distilled or deionized water.
Steam-distilled water shall not be used in the decontamination process as this type of water usually
contains elevated concentrations of metals. Decontamination solvents to be used during field
activities will be specified in CTO WP and site-specific health and safety plan.

-------
NAVFAC Pacific ER Program
Equipment Decontamination

Procedure Number:

Revision:

Page:

i-F

May 2015
4 of 5

Rinse equipment used for measuring field parameters, such as pH, temperature, specific
conductivity, and turbidity with deionized or distilled water after each measurement. Also wash new,
unused soil sample liners and caps with a fresh detergent solution and rinse them with potable water
followed by distilled or deionized water to remove any dirt or cutting oils that might be on them
prior to use.

5.5	Containment of Residual Contaminants and Cleaning Solutions

A decontamination program for equipment exposed to potentially hazardous materials requires a
provision for catchment and disposal of the contaminated material, cleaning solution, and wash
water.

When contaminated material and cleaning fluids must be contained from heavy equipment, such as
drilling rigs and support vehicles, the area must be properly floored, preferably with a concrete pad
that slopes toward a sump pit. If a concrete pad is impractical, planking can be used to construct
solid flooring that is then covered by a nonporous surface and sloped toward a collection sump. If the
decontamination area lacks a collection sump, use plastic sheeting and blocks or other objects to
create a bermed area for collection of equipment decontamination water. Situate items, such as auger
flights, which can be placed on metal stands or other similar equipment, on this equipment during
decontamination to prevent contact with fluids generated by previous equipment decontamination.
Store clean equipment in a separate location to prevent recontamination. Collect decontamination
fluids contained within the bermed area and store them in secured containers as described below.

Use wash buckets or tubs to catch fluids from the decontamination of lighter-weight drilling
equipment and hand-held sampling devices. Collect the decontamination fluids and store them on
site in secured containers, such as U.S. Department of Transportation-approved drums, until their
disposition is determined by laboratory analytical results. Label containers in accordance with
Procedure I-A-6, Investigation-Derived Waste Management.

5.6	Effectiveness of Decontamination Procedures

A decontamination program must incorporate quality control measures to determine the effectiveness
of cleaning methods. Quality control measures typically include collection of equipment blank
samples or wipe testing. Equipment blanks consist of analyte-free water that has been poured over or
through the sample collection equipment after its final decontamination rinse. Wipe testing is
performed by wiping a cloth over the surface of the equipment after cleaning. Procedure III-B, Field
QC Samples (Water, Soil) provides further descriptions of these samples and their required
frequency of collection. These quality control measures provide "after-the fact" information that may
be useful in determining whether or not cleaning methods were effective in removing the
contaminants of concern.

6.	Records

Describe the decontamination process in the field logbook.

7.	Health and Safety

Field Personnel shall perform work in accordance with the current (or as contractually obligated)
United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2008) and site-specific health and safety plan.

-------
NAVFAC Pacific ER Program
Equipment Decontamination

Procedure Number:

Revision:

Page:

i-F

May 2015
5 of 5

8.	References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/uip_qapp_vl_0305.pdf.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-A-6, Investigation-Derived Waste Management.

Procedure III-B, Field QC Samples (Water, Soil).

9.	Attachments

None.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Land Surveying

Procedure Number:

Revision:

Page:

/-/

May 2015
1 of 5

Land Surveying

1.	Purpose

This standard operating procedure sets forth protocols for acquiring land surveying data to facilitate
the location and mapping of geologic, hydrologic, geotechnical data, and analytical sampling points
and to establish topographic control over project sites for use by United States (U.S.) Navy
Environmental Restoration (ER) Program, Naval Facilities Engineering Command (NAVFAC),
Pacific personnel.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the Uniform Federal Policy-Quality Assurance Project Plan
(DoD 2005). As professional guidance for specific activities, this procedure is not intended to
obviate the need for professional judgment during unforeseen circumstances. Deviations from this
procedure while planning or executing planned activities must be approved and documented by the
following prime contractor representatives: the CTO Manager and the Quality Assurance (QA)
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

3.	Definitions

3.1	Boundary Survey

Boundary surveys are conducted by Certified Land Surveyors in order to delineate a legal property
line for a site or section of a site.

3.2	Global Positioning System (GPS)

A GPS is a system of satellites, computers, and receivers that is able to determine the latitude and
longitude of a receiver on Earth by calculating the time difference for signals from different satellites
to reach the receiver.

3.3	Waypoint

A waypoint is a reference point or set of coordinates that precisely identify a location.

4.	Responsibilities

The prime contractor CTO Manager is responsible for determining the appropriate land surveying
protocols for the project and ensuring this procedure is properly implemented. The CTO Manager is
responsible for ensuring that all personnel involved in land surveying shall have the appropriate
education, experience, and training to perform their assigned tasks as specified in Chief of Naval
Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

-------
NAVFAC Pacific ER Program
Land Surveying

Procedure Number:

Revision:

Page:

/-/

May 2015
2 of 5

The prime contractor QA Manager or Technical Director is responsible for ensuring overall
compliance with this procedure.

The Field Manager (FM) is responsible for ensuring that the appropriate protocols are conducted
according to this procedure and the project-specific sampling plan. In virtually all cases,
subcontractors will conduct these procedures. The FM is responsible for overseeing the activities of
the subcontractor and ensuring that sampling points and topographic features are properly surveyed.

Field personnel are responsible for the implementation of this procedure.

5. Procedures

5.1 Theodolite/Electronic Distance Measurement (EDM)

Follow the procedures listed below during theodolite/EDM land surveying conducted under the
NAVFAC Pacific ER Program:

A land surveyor registered in the state or territory in which the work is being performed shall
directly supervise all surveying work.

An authorized manufacturer's representative shall inspect and calibrate survey instruments
in accordance with the manufacturer's specifications regarding procedures and frequencies.
At a minimum, instruments shall be calibrated no more than 6 months prior to the start of the
survey work.

Standards for all survey work shall be in accordance with National Oceanic and Atmospheric
Administration standards and, at a minimum, with accuracy standards set forth below. The
horizontal accuracy for the location of all grid intersection and planimetric features shall be
(+) 0.1 feet. The horizontal accuracy for boundary surveys shall be 1 in 10,000 feet
(1:10,000). The vertical accuracy for ground surface elevations shall be (+) 0.1 feet.
Benchmark elevation accuracy and elevation of other permanent features, including
monitoring wellheads, shall be (+) 0.01 feet.

Reference surveys to the local established coordinate systems, and base all elevations and
benchmarks established on U.S. Geological Survey datum, 1929 general adjustment.

Reference surveyed points to mean sea level (lower low water level).

Jointly determine appropriate horizontal and vertical control points prior to the start of
survey activities. If discrepancies in the survey (e.g., anomalous water level elevations) are
observed, the surveyor may be required to verify the survey by comparison to a known
survey mark. If necessary, a verification survey may be conducted by a qualified third party.

All field notes, sketches, and drawings shall clearly identify the horizontal and vertical
control points by number designation, description, coordinates, and elevations. Map all
surveyed locations using a base map or other site mapping, as specified by the CTO
Manager.

Begin and end all surveys at the designated horizontal and vertical control points to
determine the degree of accuracy of the surveys.

-------
NAVFAC Pacific ER Program
Land Surveying

Procedure Number:

Revision:

Page:

/-/

May 2015
3 of 5

Iron pins used to mark control points shall be made of reinforcement steel or an equivalent
material and shall be 18 inches long with a minimum diameter of 5/8 inch. Drive pins to a
depth of 18 inches into the soil.

Stakes used to mark survey lines and points shall be made from 3-foot lengths of 2-inch by
2-inch lumber and pointed at one end. Clearly mark them with brightly colored weatherproof
flagging and biodegradable paint.

Clearly mark the point on a monitoring well casing that is surveyed by filing grooves into
the casing on either side of the surveyed point.

5.2 Global Positioning System (GPS) to Conduct Land Survey

Follow the procedures listed below during GPS land surveying conducted under the NAVFAC
Pacific ER Program:

A land surveyor registered in the state or territory in which the work is being performed shall
directly supervise all surveying work.

An authorized manufacturer's representative shall inspect and calibrate survey instruments
in accordance with the manufacturer's specifications regarding procedures and frequencies.
At a minimum, instruments shall be calibrated no more than 6 months prior to the start of the
survey work.

Standards for all survey work shall be in accordance with National Oceanic and Atmospheric
Administration standards and, at a minimum, with accuracy standards set forth below. The
horizontal accuracy for the location of all grid intersection and planimetric features shall be
(+) 0.1 feet. The horizontal accuracy for boundary surveys shall be 1 in 10,000 feet
(1:10,000). The vertical accuracy for ground surface elevations shall be (+) 0.1 feet.
Benchmark elevation accuracy and elevation of other permanent features, including
monitoring wellheads, shall be (+) 0.01 feet. Accuracy requirements shall be specified in the
project work plan (WP).

Reference surveys to the local established coordinate systems, and base all elevations and
benchmarks established on U.S. Geological Survey datum, 1929 general adjustment.

All field notes, sketches, and drawings shall clearly identify the horizontal and vertical
control points by number designation, description, coordinates, and elevations. Map all
surveyed locations using a base map or other site mapping, as specified in the project WP.

Begin and end all surveys at the designated horizontal and vertical control points (as
applicable) to determine the degree of accuracy of the surveys.

Iron pins used to mark control points shall be made of reinforcement steel or an equivalent
material and shall be 18 inches long with a minimum diameter of 5/8 inch. Drive pins to a
depth of 18 inches into the soil.

Stakes used to mark survey lines and points shall be made from 3-foot lengths of 2-inch by
2-inch lumber and pointed at one end. Clearly mark them with brightly colored weatherproof
flagging and biodegradable paint.

Clearly mark the point on a monitoring well casing that is surveyed by filing grooves into
the casing on either side of the surveyed point.

-------
NAVFAC Pacific ER Program
Land Surveying

Procedure Number:

Revision:

Page:

/-/

May 2015
4 of 5

5.3 Global Positioning System (GPS) to Position Sample Locations or Locate
Site Features

Experienced field personnel may use a GPS system unit to position sample locations (e.g. grid
positioned samples) at a site. The decision to use field personnel or a licensed land surveyor will
depend on the objectives of the survey (e.g. vertical elevation is not required) and the levels of
precision required. Typically when a level of precision greater than (+) 3 to 5 meters is required, a
licensed surveyor will be required. When a level of precision of (+) 3 to 5 meters is sufficient to
meet project requirements (i.e., when laying sampling grids, identifying significant site features, or
locating features identified in geographic information system [GIS] figures) experienced field
personnel may use commercially available, consumer-grade GPS units. Follow the procedures listed
below to locate samples or site features using GPS:

A commercially available GPS unit with wide angle averaging system (WAAS), topographic
map display, and waypoint storage capabilities should be used.

If waypoints are to be imported into a GIS database, the same grid projection system should
be used. For Guam this is typically WGS84, Zone 55N. For Hawaii this will either be
NAD83 Zone 3 and 4 or WGS84 Zone 5N.

If a permanent reference point near the site is available, it is recommended that the reference
point is surveyed each day the GPS unit is used.

When laying out a sampling grid from a GIS map, upload the coordinates from GIS to the
GPS unit, including coordinates for an easily identified, permanent, nearby feature
(i.e., building corner, roadway intersection, or USGS benchmark).

If during the initial site walk, the permanent feature identified does not overlay within
(+) 5 meters as identified in the GPS unit, field corrections of the waypoints should be made.

Field corrections can be made by adding/subtracting the difference in x,y coordinates
between the field measurement of the permanent site feature and the anticipated x,y
coordinates. This correction should then be applied to the x,y coordinates for each sampling
location to be marked. Corrected x,y coordinates can then be uploaded into the GPS unit.

Sampling points and site features can then be located in the field using the GPS units "Go
To" function. When the distance to the sampling point or feature remains close to zero, the
location can be marked.

If no field corrections to the sampling location need to be made, or if sampling locations are
to be surveyed by a licensed surveyor at a later date, no additional waypoints need to be
taken. If significant changes to the sampling location are made, GPS coordinates at the
corrected location shall be stored and labeled.

It is recommended that GPS coordinates be uploaded to a storage device such as a personal
computer at the end of each day.

Field logs shall indicate manufacturer and model number for GPS unit used, map datum and
projection used, and any field corrections made. If the GPS unit cannot lock onto a WAAS
system at the site, this should also be noted.

-------
NAVFAC Pacific ER Program
Land Surveying

Procedure Number:

Revision:

Page:

/-/

May 2015
5 of 5

6.	Records

The surveyor shall record field notes daily using generally accepted practices. The data shall be neat,
legible, and easily reproducible. Copies of the surveyor's field notes and calculation forms generated
during the work shall be obtained and placed in the project files.

Surveyor's field notes shall, at a minimum, clearly indicate:

The date of the survey
General weather conditions
The name of the surveying firm

The names and job titles of personnel performing the survey work
Equipment used, including serial numbers
Field book designations, including page numbers

A land surveyor registered in the state or territory in which the work was done shall sign, seal, and
certify the drawings and calculations submitted by the surveyor.

Dated records of land surveying equipment calibration shall be provided by the surveyor and placed
in the project files. Equipment serial numbers shall be provided in the calibration records.

7.	Health and Safety

Field personnel shall perform work in accordance with the current (or as contractually obligated)
United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2008) and site-specific health and safety plan.

8.	References

Department of Defense, United States (DoD). 2005. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/uip_qapp_vl_0305.pdf.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

9.	Attachments

None.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
1 of 39

Data Validation	

1.	Purpose

This procedure describes the presentation format and information provided in the data validation
reports under the United States (U.S.) Navy Environmental Restoration (ER) Program for Naval
Facilities Engineering Command (NAVFAC), Pacific. The objective of data validation is to provide
data of known quality to the end user. This procedure also establishes the method by which a
Contract Task Order (CTO) Manager selects and confirms the content of data validation reports and
is consistent with protocol in the Department of Defense Quality Systems Manual (QSM) for
Environmental Laboratories (DoD QSM) (DoD 2013).

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the most recent version of the Uniform Federal Policy-Quality
Assurance Project Plan (UFP QAPP) Part 1 (DoD 2005a), 2A (DoD 2012) and 2B (2005b) as well as
the DoD Quality Systems Manual (DoD 2013). As professional guidance for specific activities, this
procedure is not intended to obviate the need for professional judgment during unforeseen
circumstances. Deviations from this procedure while planning or executing planned activities must
be approved and documented by the following prime contractor representatives: the CTO Manager
and the Quality Assurance (QA) Manager or Technical Director. A Navy project representative
(i.e., Remedial Project Manager or QA manager) shall also concur with any deviations.

3.	Definitions

Acronyms and abbreviations used in all data validation procedures and reports are defined in
Attachment II-A-1. Commonly used terms are defined in Attachment II-A-2.

4.	Responsibilities

The CTO Manager, the QA Manager or Technical Director, and the CTO QA Coordinator are
responsible for ensuring that this procedure is implemented by data validation personnel.

Data validation personnel are responsible for implementing this procedure for all data validation
reports.

5.	Procedure

5.1 Introduction

This procedure addresses the validation of data obtained under the NAVFAC Pacific ER Program
using primarily U.S. Environmental Protection Agency (EPA) Solid Waste (SW)-846 methods
(EPA 2007). Based on the data validation requirements identified in the CTO project planning
documents, the analytical data may undergo "Level B," "Level C," or "Level D" data validation or

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
2 of 39

some combination of these validation levels. This procedure establishes the required format and
content of the various validation reports.

5.1.1 Confirmation of Data Validation Reports

Prior to shipment of all completed data validation reports to the CTO Manager, a single draft report
for one sample delivery group (SDG) should be submitted. The CTO Manager shall review the draft
report to confirm that the report contains the requested information, and respond to the Data
Validation Project Manager in a timely manner. Once the requested contents are confirmed, the
complete data validation packages should be delivered to the CTO Manager.

5.2 Content And Format of the Data Validation Report

The data validation report will consist of the following four major components:

1.	Cover letter

2.	Data validation reference package comprising:

a.	Cover page

b.	Acronyms and abbreviations list

c.	Data qualifier reference table

d.	Qualification code reference table

3.	Individual data validation reports by SDG:

e.	Cover page

f.	Introduction

g.	Data validation findings

h.	Appendix of laboratory reports with applied data qualifiers

A discussion of the contents and format of these components is provided in the following sections.

5.2.1	Cover Letter

The cover letter will contain the generation date of the cover letter, the address of the CTO office,
the CTO number, and the CTO Manager's name or designee. The cover letter will list the specific
reports being sent under that cover letter. A senior data reviewer must review the report and sign the
cover letter to denote approval. Attachment II-A-3 is an example of the cover letter.

5.2.2	Data Validation Reference Package

One data validation reference package shall be provided per CTO and shall contain the reference
information needed for interpretation of the individual data validation reports. The following sections
shall be included:

5.2.2.1 Cover Page

The cover page shall indicate the CTO title and number to which the reference package applies.

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
3 of 39

5.2.2.2	Acronyms and Abbreviations List

This list shall present all acronyms and abbreviations used in the individual data validation reports.
Attachment II-A-1 is an example of the acronyms and abbreviations list.

5.2.2.3	Da ta Qualifier Reference Table

Data qualifiers are applied in cases where the data do not meet the required quality control (QC)
criteria or where special consideration by the data user is required.

The data qualifier reference table lists the data qualifiers used in the validation of the analytical data.
Attachment II-A-4 is an example of this table.

5.2.2.4	Qualification Code Reference Table

Qualification codes explain why data qualifiers have been applied and identify possible limitations of
data use. Attachment II-A-5 provides the qualification codes used by the NAVFAC Pacific ER
Program. Qualification codes are to be provided by data validation personnel on the annotated
laboratory reports discussed in Section 5.2.3.4.

5.2.3 Individual Data Validation Reports by SDG

For all analyses, each SDG shall have a unique data validation report. The procedures used to
generate the reports are discussed in the following sub-sections.

5.2.3.1	Cover Page

The cover page shall indicate the CTO title and number, analysis type, and the SDG(s), which the
report addresses.

5.2.3.2	Introduction

This section will contain a brief description of the CTO information that is pertinent to data
validation. This information includes the CTO title and number, CTO Manager, the sample matrices
and analyses performed on the samples, the data validation level for the project, and a brief
discussion of the methodologies used for data validation. This section will also contain a Sample
Identification Table which lists the identification of each sample identification number cross
referenced with its associated internal laboratory identification number and COC sample number.
Each sample will be listed under every analytical method for which data was validated.
Attachment II-A-6 is an example of the sample identification table.

5.2.3.3	Da ta Valida tion Findings

This section shall present the data validation findings of the data reviewer for the CTO data package.
The findings shall be determined on the basis of validation criteria established for each analytical
method1 in the DoD QSM (DoD 2013) or the CTO planning document and Procedure II-B through
Procedure II-X. For all data validation levels, the data validation findings are divided into the
following analytical categories:

II-B GC/MS Volatile Organics by SW-846 Method 8260

1 Other methods may be included with approval of the CTO and Data Validation Managers.

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
4 of 39

II-C GC/MS Semivolatile Organics by SW-846 8270 (full scan and SIM)

II-D HRGC/HRMS Polychlorinated Dibenzodioxins (PCDDs) and Polychlorinated
Dibenzofurans (PCDFs) by SW-846 8290

II-E Organochlorine Pesticides by SW-846 8081

II-F Polychlorinated Biphenyls as Aroclors by SW-846 8082

II-G Polychlorinated Biphenyls as Congeners by SW-846 8082

II-H Total Petroleum Hydrocarbons by SW-846 8015

II-I Chlorinated Herbicides by SW-846 8151

II-J Organophosphorus Pesticides by SW-846 8141

II-K Halogenated and Aromatic Volatiles by SW-846 8021

. II-L Phenols by SW-846 8041

II-M Ethylene Dibromide/Dibromochloropropane by SW-846 8011

II-N Polynuclear Aromatic Hydrocarbons by SW-846 8310

. II-O Explosives by SW-846 8330

II-P Carbamate and Urea Pesticides by EPA Method 632

. II-Q Metals by EPA Method SW-846 6000/7000

II-R Wet Chemistry Analyses

II-S Data Quality Assessment Report

II-T HRGC/HRMS Polychlorinated Biphenyls as Congeners by EPA Method 1668

II-U Carbamate and Urea Pesticides by SW-846 8321

. II-V Perchlorate by SW-846 6850

II-W GC/FID/ECD Volatile Organics and Fixed Gases in Soil Gas/Vapor by EPA Method
TO-3 and ASTM D1946

II-X GC/MS Volatile Organics and Fixed Gases in Soil Gas/Vapor by EPA Method TO-14,
TO-15, and TO-17

GC/MS	gas chromatography/mass spectrometry

ECD	electron capture detector

FID	flame ionization detector

HRGC/HRMS	high resolution gas chromatograph/high resolution mass spectrometer

SIM	selective ion monitoring

Level C and Level D Data Validation

Data obtained using any analytical methods in the above categories will be validated in terms of
meeting criteria for specific QA/QC factors such as holding times, instrument calibration, and blank
analyses. A separate discussion of each QA/QC factor under each analytical method will be

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
5 of 39

presented in the CTO data validation report. The QA/QC factors used to validate data for Level C
and Level D validation are presented below for each analytical category.

Volatile Organics by Gas Chromatography/Mass Spectrometry (GC/MS)

1.	Sample management (sample preservation, handling, and transport, chain-of-custody, and
holding times)

2.	GC/MS instrument performance check

3.	Calibration (initial calibration, initial calibration verification, and continuing calibration)

4.	Method blanks

5.	Blank spikes and laboratory control samples (LCSs)

6.	Surrogate recovery

7.	Matrix spike/matrix spike duplicate (MS/MSD)

8.	Field QC samples (trip blanks, equipment blanks, field blanks, field duplicates, and field
triplicates)

9.	Internal standards performance

10.	Target compound identification (Level D only*)

11.	Compound quantitation and reporting limits (RLs) (Level D only*)

12.	Tentatively identified compounds (Level D only*)

13.	System performance (Level D only*)

Semivolatile Organics by Full Scan and SIM GC/MS

1.	Sample management (sample preservation, handling, and transport; chain-of-custody;
holding times)

2.	GC/MS instrument performance check (full scan)

3.	Calibration (initial calibration, initial calibration verification, and continuing calibration)

4.	Method blanks

5.	Blank spikes and LCSs

6.	Surrogate recovery

7.	MS/MSD

8.	Field QC samples (equipment blanks, field blanks, and field duplicates)

9.	Internal standards performance

10.	Target Compound identification (Level D only*)

11.	Compound quantitation and RLs (Level D only*)

12.	Tentatively identified compounds (Level D only*)

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
6 of 39

13. System performance (Level D only*)

Dioxins/Dibenzofurans by HRGC/HRMS

1.	Sample management (sample preservation, handling, and transport; chain-of-custody;
holding times)

2.	HRGC/HRMS instrument performance check

3.	Calibration (initial calibration, initial calibration verification, and continuing calibration)

4.	Method blanks

5.	Blank spikes and LCSs

6.	MS/MSD

7.	Field QC samples (equipment blanks, field blanks, field duplicates, and field triplicates)

8.	Internal standards performance

9.	Target compound identification (Level D only*)

10.	Compound quantitation and RLs (Level D only*)

11.	System performance (Level D only*)

Organochlorine Pesticides by GC

1.	Sample management (sample preservation, handling, and transport; chain-of-custody;
holding times)

2.	Pesticides instrument performance (retention time evaluation, 4,4'-DDT/Endrin breakdown
evaluation)

3.	Calibration (analytical sequence, initial calibration, initial calibration verification, continuing
calibration)

4.	Method blanks

5.	Blank spikes and LCSs

6.	Surrogate recovery

7.	MS/MSD

8.	Sample cleanup performance

9.	Field QC samples (equipment blanks, field blanks, field duplicates, and field triplicates)

10.	Target compound identification (Level D only*)

11.	Compound quantitation and RLs (Level D only*)

Organic Analyses by GC (QA/QC factors may vary depending on analysis type)

1. Sample management (sample preservation, handling, and transport; chain-of-custody;
holding times)

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
7 of 39

2.	Instrument performance

3.	Calibration (initial calibration, initial calibration verification and continuing calibration)

4.	Method blanks

5.	Blank spikes and LCS

6.	Surrogate recovery

7.	MS/MSD

8.	Field QC samples (trip blanks [volatile organic compounds], equipment blanks, field blanks,
field duplicates, and field triplicates)

9.	Target compound identification (Level D only*)

10.	Compound quantitation and RLs (Level D only*)

Organic Analyses by High-Performance Liquid Chromatography (QA/QC factors may vary
depending on analysis type)

1.	Sample management (sample preservation, handling, and transport; chain-of-custody;
holding times)

2.	Instrument performance

3.	Calibration (initial calibration, initial calibration verification and continuing calibration)

4.	Method blanks

5.	Blank spikes and LCSs

6.	Surrogate recovery

7.	MS/MSD

8.	Field QC samples (equipment blanks, field blanks, field duplicates, and field triplicates)

9.	Target compound identification (Level D only*)

10.	Compound quantitation and reporting limits (RLs) (Level D only*)

Organic Analyses by Liquid Chromatography-Mass Spectrometry (QA/QC factors may vary
depending on analysis type)

1.	Sample management (sample preservation, handling, and transport; chain-of-custody;
holding times)

2.	Instrument performance

3.	Calibration (initial calibration, initial calibration verification, and continuing calibration)

4.	Method blanks

5.	Blank spikes and LCSs

6.	MS/MSD

7.	Field QC samples (equipment blanks, field blanks, field duplicates, and field triplicates)

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
8 of 39

8.	Internal standards performance

9.	Target compound identification (Level D only*)

10.	Compound quantitation and RLs (Level D only*)

Metals

1.	Sample management (sample preservation, handling, and transport; chain-of-custody;
holding times)

2.	Calibration (initial and continuing)

3.	Blanks (Calibration blanks and Method [preparation] blanks)

4.	Inductively coupled (argon) plasma (spectroscopy) (ICP) interference check sample

5.	Blank spikes and LCSs

6.	MS/MSD and Matrix duplicates

7.	Furnace atomic absorption QC

8.	Internal standards performance (MS methods only)

9.	ICP serial dilution

10.	Sample result verification (Level D only*)

11.	Field QC samples (equipment blanks, field blanks, field duplicates, and field triplicates)

Inorganic Analyses by Wet Chemical Methods, (QA/QC factors may vary depending on analysis
type)

1.	Sample management (sample preservation, handling, and transport; chain-of-custody; and
holding times)

2.	Calibration (initial and continuing)

3.	Method blanks

4.	Blank spikes and LCSs

5.	MS/MSD and Matrix duplicates

6.	Sample result verification (Level D only*)

7.	Field QC samples (equipment blanks, field blanks, field duplicates, and field triplicates)

* Sections applicable to Level D validation only will also appear in Level C validation reports with the notation "not applicable
for Level C validation."

Level B Data Validation

Data obtained using any analytical methods in the Level B Validation analytical categories will be
validated in terms of meeting criteria for specific QA/QC factors such as holding times, blank spike

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
9 of 39

analyses, and blank analyses. A separate discussion of each QA/QC factor under each analytical
method will be presented in the CTO data validation report. The QA/QC factors used to validate data
for QA/QC "Level B Validation" are presented below for each analytical category.

Organic Analyses

1.	Sample management (sample preservation, handling, and transport; chain-of-custody; and
holding times)

2.	Method blanks

3.	Blank spikes and laboratory control samples

4.	Field QC samples (trip blanks (volatile organic compounds), equipment blanks, field blanks,
field duplicates, and field triplicates)

5.	Surrogate recovery

6.	MS/MSD

Inorganic Analyses

1.	Sample management (sample preservation, handling, and transport; chain-of-custody; and
holding times)

2.	Blanks (Calibration and Method blanks)

3.	Blank spikes and LCSs

4.	Field QC samples (equipment blanks, field blanks, field duplicates, and field triplicates)

5.	MS/MSD and Laboratory Duplicates

6.	ICP serial dilution

5.2.3.4 Laboratory Reports

Annotated laboratory reports with the appropriate data qualifiers and qualification codes as specified
in the NAVFAC Pacific ER Program data validation procedures will be submitted as an appendix to
the data validation report. An example is provided as Attachment II-A-7. Records

Copies of all documents generated by data validation personnel will be stored for no less than
10 years. The original validated laboratory data shall be archived to the Federal Records Center at
project completion.

6. References

Department of Defense, United States (DoD). 2005a. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
10 of 39

	. 2005b. Uniform Federal Policy for Quality Assurance Project Plans, Part 2B: Quality

Assurance/quality Control Compendium: Minimum QA/QC Activities. Final Version 1. DoD:
DTIC ADA 426957, EPA-505-B-04-900B. In conjunction with the U. S. Environmental
Protection Agency and the Department of Energy. Washington: Intergovernmental Data Quality
Task Force. March. On-line updates available at: http://www.epa.gov/swerffrr/pdf/-
qaqc_v 1 03 05 .pdf.

	. 2012. Uniform Federal Policy for Quality Assurance Project Plans, Part 2A: Optimized

UFP-QAPP Worksheets. Revision 1. March.

	. 2013. Department of Defense Quality Systems Manual for Environmental Laboratories.

Version 5.0. Draft Final. Prepared by DoD Environmental Data Quality Workgroup and
Department of Energy Consolidated Audit Program Operations Team. July.

Environmental Protection Agency, United States (EPA). 2007. Test Methods for Evaluating Solid
Waste, Physical/Chemical Methods, SW-846. 3rd ed., Final Update IV. Office of Solid Waste.
On-line updates at: www.epa.gov/epaoswer/hazwaste/test/new-meth.htm.

7. Attachments

Attachment II-A-1: Acronyms and Abbreviations
Attachment II-A-2: Definition of Terms
Attachment II-A-3: Sample Cover Letter
Attachment II-A-4: Data Qualifier Reference Table
Attachment II-A-5: Qualification Code Reference Table
Attachment II-A-6: Sample Identification Table

Attachment II-A-7: Example Annotated Laboratory Report Volatile Organics Analysis Data Sheet

-------
Attachment ll-A-1
Acronyms and Abbreviations

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
13 of 39

ACRONYMS AND ABBREVIATIONS

Following is a list of acronyms and abbreviations that may be used in NAVFAC Pacific ER Program
data validation reports and the data quality assessment reports.

%D

percent difference

%R

percent recovery

Mg/kg

microgram per kilogram

l-ig/L

microgram per liter

4,4'-DDD

4,4'-dichlorodiphenyldichloroethane

4,4'-DDE

4,4'-dichlorodiphenyldichloroethylene

4,4'-DDT

4,4'-dichlorodiphenyltrichloroethane

AA

atomic absorption

ARRF

average relative response factor

BFB

bromofluorobenzene

BNA

base/neutral/acid

CCB

continuing calibration blank

CCC

calibration check compound

CCV

continuing calibration verification

CF

calibration factor

CLP

Contract Laboratory Program

COC

chain-of-custody

COD

chemical oxygen demand

CTO

contract task order

CVAA

cold vapor atomic absorption

DBCP

Dibromochloropropane

DCB

decachlorobiphenyl

DFTPP

decafluorotriphenylphosphine

DL

detection limit

DoD

Department of Defense

DOE

Department of Energy

DQAR

data quality assessment report

DUP

laboratory duplicate

DVP

data validation procedure

EB

equipment blank

EDB

ethylene dibromide

EDL

estimated detection limit

EICP

extracted ion current profile

EPA

Environmental Protection Agency, United States

FB

field blank

GC

gas chromatography

GC/ECD

gas chromatography/electron capture detector

GC/ELCD

gas chromatography/electrolytic conductivity detector (Hall detector)

GC/FPD

gas chromatography/flame photometric detector

GC/MS

gas chromatography/mass spectrometry

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
14 of 39

GC/PID

gas chromatography/photoionization detector

GFAA

graphite furnace atomic absorption

GPC

gel permeation chromatography

Hg

mercury

HPLC

high-performance liquid chromatography

HRGC/HRMS

high resolution gas chromatography/high resolution mass spectrometry

HT

holding time

ICB

initial calibration blank

ICP

inductively coupled plasma

ICS

interference check sample

ICV

initial calibration verification

IDL

instrument detection limit

IR

infrared spectroscopy

IRP

installation restoration program

IS

internal standards

LCS

laboratory control sample

LOD

limit of detection

LOQ

limit of quantitation

m/z

mass to charge ratio

MBAS

methyl blue active substance

mg/kg

milligram per kilogram

mg/L

milligram per liter

MS

matrix spike

MSA

method of standard addition

MSD

matrix spike duplicate

NFESC

Naval Facilities Engineering Services Center

ng/kg

nanogram per kilogram

OP

organophosphorus

PAH

polynuclear aromatic hydrocarbon

PARCC

precision, accuracy, representativeness, comparability, completeness

PCB

polychlorinated biphenyl

PCDD

polychlorinated dibenzodioxin

PCDF

polychlorinated dibenzofuran

PE

performance evaluation

PEM

performance evaluation mixture

PFK

perfluorokerosene

Pg/g

picogram per gram

pg/L

picogram per liter

PQO

project quality objective

QA

quality assurance

QAC

quality assurance coordinator

QAPP

quality assurance project plan

QC

quality control

QSM

quality system manual

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
15 of 39

r

correlation coefficient

r2

coefficient of determination

RF

response factor

RIC

reconstructed ion chromatogram

RL

reporting limit

RPD

relative percent difference

RRF

relative response factor

RRT

relative retention time

RSD

relative standard deviation

RT

retention time

s/n

signal to noise ratio

SDG

sample delivery group

SICP

selected ion current profiles

SOP

standard operating procedure

SOW

statement of work

SPCC

system performance check compound

SRM

standard reference material

SVOC

semivolatile organic compound

TB

trip blank

TCDD

tetrachlorodibenzodioxin

TCX

tetrachloro-m-xylene

TDS

total dissolved solids

TIC

tentatively identified compound

TOC

total organic carbon

TOX

total organic halides

TPHE

total petroleum hydrocarbons as extractables

UV/VIS

ultraviolet/visible

VOA

volatile organic analysis

VOC

volatile organic compound

VTSR

validated time of sample receipt

WDM

window defining mixture

-------
This page intentionally left blank

-------
Attachment ll-A-2
Definition of Terms

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
19 of 39

DEFINITION OF TERMS

Calibration
Curve

CCB
CCV
EDL

Field Blank

Field Duplicate
Findings

GPC

Holding Time
ICB

ICV

Initial
Calibration

IR
IS

Laboratory
Duplicate

MDL

MS

m/z

A plot of response versus concentration of standards.

Continuing Calibration Blank - a deionized water sample run every 10
samples designed to detect any carryover contamination.

Continuing Calibration Verification - a standard run every 10 samples to
test instrument performance.

Estimated Detection Limit - The sample specific EDL is the concentration
of a given analyte required to produce a signal with a peak height of at least
2.5 times the background signal level.

Field blanks are intended to identify contaminants that may have been
introduced in the field through source water.

A duplicate sample generated in the field, not in the laboratory.

Any out-of-control, unacceptable, or out of criteria event which may impact
the quality of the data or require corrective action.

Gel Permeation Chromatography - A sample clean-up technique that
separates compounds by size and molecular weight. Generally used to
remove oily materials from sample extracts.

The time from sample collection to sample analysis.

Initial Calibration Blank - the first blank standard run to confirm the
calibration curve.

Initial Calibration Verification - the first standard run to confirm the
calibration curve.

The establishment of a calibration curve with the appropriate number of
standards and concentration range. The calibration curve plots instrument
response versus concentration of standards.

Infrared Spectroscopy.

Internal Standards - compounds added to every VOA and BNA standard,
blank, matrix spike duplicate, and sample extract at a known concentration,
prior to instrumental analysis. Internal standards are used as the basis for
quantitation of the target compounds.

A duplicate sample generated in the laboratory.

Method Detection Limit - minimum concentration of a substance that can
be measured and reported with 99% confidence that the analyte
concentration is greater than zero.

Matrix Spike - introduction of a known concentration of analyte into a
sample to provide information about the effect of the sample matrix on the
extraction or digestion and measurement methodology.

The ratio of mass (m) to charge (z) of ions measured by GC/MS.

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number:

Revision:

Page:

il-A
May 2015
20 of 39

Post Digestion
Spike

Primary Analysis

QA
QC

RL

RPD

Serial Dilution
SDG

LevelB
Validation

Level C Data
Validation

Level D Data
Validation

The addition of a known amount of standard after digestion. (Also
identified as analytical spike or spike for furnace analysis).

One of two types of pesticide/PCB analysis by GC/EC techniques, the other
being confirmation analysis. The primary analysis is used to establish the
tentative identification of any pesticides/PCBs detected. The identification
is confirmed in the confirmation analysis. If the two analyses are done
simultaneously, either may be considered the primary analysis. Either may
be used for quantitation if contract criteria are met.

Quality Assurance - total program for assuring the reliability of data

Quality Control - routine application of procedures for controlling the
monitoring process.

Reporting Limit - value specified by the client based on sensitivity
requirements from project-specific action levels.

Relative Percent Difference (between matrix spike and matrix spike
duplicate, duplicate laboratory control samples, or blank spikes)

A sample run at a specific dilution to determine whether any significant
chemical or physical interferences exist due to sample matrix effects (ICP
only).

Sample Delivery Group - defined by one of the following, whichever
occurs first:

•	Case of field samples

•	Each 20 field samples within a case

•	Each 14-day calendar period during which field samples in a case are

received, beginning with receipt of the first sample in the SDG

Data validation is performed using sample results and QA/QC summaries
(i.e., method blanks, LCS, MS/MSDs, surrogates, and serial dilutions).

This level of data validation was previously identified as "Standard."

Data validation is performed using sample results and QA/QC summaries
(including instrument performance, calibration, and internal standard data).
This level of data validation was previously identified as "Cursory."

Data validation is performed using sample results, QA/QC summaries
(including instrument performance, calibration, and internal standard data)
and raw data associated to the sample results and QA/QC summaries. This
level of data validation was previously identified as "Full."

-------
Attachment ll-A-3
Sample Cover Letter

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number

Revision

Page

il-A
May 2015
23 of 39

SAMPLE COVER LETTER

(Date)

(CTO Manager or designee) (company address) Dear ( ): Enclosed is Revision	of the data

validation reports for CTO (number) as follows: Semi-volatiles SDG S0221 SDG S0350
Pesticides/PCBs SDG S0201 Metals SDG S0221 SDG S0201 The specific sample
identifications are listed in the Sample Identification Table(s). The data packages were reviewed
according to the data validation procedures referenced in the introduction to each report.

Sincerely,

(Signature)

Data Validation Project Manager

-------
This page intentionally left blank

-------
Attachment ll-A-4
Data Qualifier Reference Table

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number	il-A

Revision	May 2015

Page	27 of 39

Table ll-A-4-1: Data Qualifier Reference Table

Qualifier

Organics

Inorganics

U

The analyte was analyzed for, but was not detected
above the method detection limit.

The analyte was analyzed for, but was not detected
above the method detection limit.

J

The analyte was positively identified; the associated
numerical value is the approximate concentration of
the analyte in the sample.

The result is an estimated quantity. The associated
numerical value is the approximate concentration of
the analyte in the sample.

N

The analysis indicates the presence of an analyte for
which there is presumptive evidence to make a
"tentative identification."

Not applicable.

NJ

The analysis indicates the presence of an analyte
that has been "tentatively identified" and the
associated numerical value represents its
approximate concentration.

Not applicable.

UJ

The analyte was not detected above the method
detection limit. However, the associated value is
approximate and may or may not represent the actual
limit of quantitation necessary to accurately and
precisely measure the analyte in the sample.

The analyte was analyzed for, but was not detected.
The associated value is an estimate and may be
inaccurate or imprecise.

R

The sample results are rejected due to serious
deficiencies in the ability to analyze the sample and
to meet quality control criteria. The presence or
absence of the analyte cannot be verified.

The data are unusable. The sample results are
rejected due to serious deficiencies in meeting the
Quality Control (QC) criteria. The analyte may or may
not be present in the sample.

-------
This page intentionally left blank

-------
Attachment ll-A-5
Qualification Code Reference Table

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number	il-A

Revision	May 2015

Page	31 of 39

Table ll-A-5-1: Qualification Code Reference Table

Qualifier

Organics

Inorganics

H

Holding times were exceeded.

Holding times were exceeded.

S

Surrogate recovery was outside QC limits.

The sequence or number of standards used for the
calibration was incorrect.

C

Calibration %RSD, r, r2 or %D were noncompliant

Correlation coefficient is <0.995.

R

Calibration RRF was <0.05.

%R for calibration is not within control limits

B

Presumed contamination from preparation (method
blank)

Presumed contamination from preparation
(method) blank or calibration blank

L

Laboratory Control Sample/Laboratory Control Sample
Duplicate %R or RPD was not within control limits

Laboratory Control Sample/Laboratory Control
Sample Duplicate %R or RPD was not within
control limits

Q

MS/MSD recovery was poor

MS/MSD recovery was poor.

E

MS/MSD or Duplicate RPD was high.

MS/MSD or Duplicate RPD or difference was high.

I

Internal standard performance was unsatisfactory

I CP ICS results were unsatisfactory.

A

Not applicable.

ICP Serial Dilution %D were not within control limits

M

Instrument Performance Check (BFB or DFTPP) was
noncompliant

Not applicable.

T

Presumed contamination from trip blank.

Not applicable.

F

Presumed contamination from FB or ER.

Presumed contamination from FB or ER.

D

The analysis with this flag should not be used because
another more technically sound analysis is available.

The analysis with this flag should not be used
because another more technically sound analysis is
available.

P

Instrument performance for pesticides was poor

Post Digestion Spike recovery was not within
control limits

V

Unusual problems found with the data that have been
described in the validation report where a description of
the problem can be found.

Unusual problems found with the data that have
been described in where a description of the
problem can be found.

-------
This page intentionally left blank

-------
Attachment ll-A-6
Sample Identification Table

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number	il-A

Revision	May 2015

Page	35 of 39

Table ll-A-6-1: Sample Identification Table

EPA Identification

Sample Identification

Lab Identification Number

COC Sample Number

Matrix

FB001

FB-BS04-E01-D10.0

2720-1

DA001

water

FB002

FB-BS04-B01-D10.0

2720-2

DA002

water

FB003

FB-BS04-B02-D10.0

2720-3

DA003

water

FB004

FB-SS01-S01 -D0.5

2720-4

DA004

soil

FB005

FB-BS01-S01-D10.0

2720-5

DA005

soil

FB006

FB-SS02-S01-D0.5

2720-6

DA006

soil

FB007

FB-BS02-S01-D10.0

2720-7

DA007

soil

FB008

FB-BS02-D01-D10.0

2720-8

DA008

soil

FB009

FB-SS03-S01-D0.5

2720-9

DA009

soil

FB010

FB-BS03-S01-D10.0

2720-10

DA010

soil

-------
This page intentionally left blank

-------
Attachment ll-A-7
Example Annotated Laboratory Report
Volatile Organics Analysis Data Sheet

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Data Validation

Procedure Number	ll-A

Revision	May 2015

Page	39 of 39

EXAMPLE ANNOTATED LABORATORY REPORT
VOLATILE ORGANICS ANALYSIS DATA SHEET

1A

VOLATILE ORGAMICS ANALYSIS DATA SHEET

EPA SAMPLE NO,

CA145

Lai! Name: COLUMBIA ANALYTICAL SSRVI Contract: EARTH TECH
Lab Code: COLOMB Case No.:	SAS No.:	SDG Ho.: K9804746

Matrix: (soil/water) SOIL

Sample wt/vol:	5.1 tg/mL) G

Level: (lew/filed) LOW

% Moisture: not dec. 11

GC Column: RTX-624 ID: 0.32 (ram)

Soil Extract Volume:	(uL)

CAS NO.

COMPOUND

Lab Sample ID: K980474S-013

Lab Pile ID: 0727F0Q9

Date Received: 07/17/98

Date Analyzed: 07/27/98

Dilution Factor: 1.0

Soil Aliquot Volume:	(uL)

CONCENTRATION UNITS:

(ug/L or ug/Kg) UG/KG	Q

74-87-3	

74-83-	9		

75-01-	4	

75-00-3	

75-09-2	

67-64-1	

75-15-0-'	

75-35-4	

75-34-3	-

540-59-0	

67-66-3	

107-06-	2	

78-93-3	-

71-55-6	

56-23-5	

75-27-4	

78-87-	5	

10061-01-5	

79-01-	6	

124-48-1	

79-00-5-	

71-43-2	

10061-02-6	

75-25-2	

10S-10-1	-

591-78-6	

127-18-4	

79-34-5		

108-88-	3	

108-90-7	

100-41-4	

10Q-42-5	

1330-20-7	

-Chloromethane
-Bromomethane
-Vinyl Chloride
-Chioroethane

-Methylene Chloride_
-Acetone

-Carbon Disulfide

-1,1-Dichloroethene	

-1,1-Dichloroethane

-1, 2-Dichloroethene (total)

-chloroform 	"

-1,2-Dichloroethane
-2-Butanone

--1,1,l-Trichloroethane_

—Carbon Tetrachloride	

--Bromodichloromethane
-1,2-Dichloropropane_

-cis-1,3-Dichloropropene_
-Trichloroethene

--Dibromochloromethane
--1,1,2-Trichloroethane _
--Benzene

- trains -1,3 -Dichloropropene
-Bromoform

-4 -Methyl-2 -Pentonone

-2 -Hexanone 	

- Tetrachloroet her.e

-1,1,2,2-Tetrachloroethane^
-Toluene

-Chlorobenzene_

-Ethylbenz ene	

-Styrene

—Xylene (Total)

FORM I VOA

11

0

k

11

U



11

u



11

u'

/

0.8

JBllU-

2

JB ly

11

u IA

11





11

u



11

D



11

u



11

u



11

u



11

u



11

u



11

u



11

u



11

u



11

u



11

u



11

u



11

u



11

u



11

u



11
11



/

0.2

jJ

11

UlA

0.2

JB [IU-

11

u iA

11

U IK

0.4

JB

fi IA

0.2

JB

?i V

|£)

)
%



01513

U.S. NAVY PACDIV [RP VALIDATED"

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program

Procedure Number:

lll-A

Laboratory QC Samples (Water, Soil)

Revision:

May 2015



Page:

1 of 5

Laboratory QC Samples (Water, Soil)

1.	Purpose

This section sets forth the standard operating procedure for identifying the number and type of
laboratory quality control (QC) samples that will be analyzed during each contract task order (CTO)
associated with the United States Navy Environmental Restoration (ER) Program, Naval Facilities
Engineering Command (NAVFAC), Pacific. Laboratory QC analyses serve as a check on the
precision and accuracy of analytical methods and instrumentation, and the potential contamination
that might occur during laboratory sample preparation and analyses. Laboratory QC analyses include
blank, surrogate, blank spike, laboratory control sample (LCS), and matrix spike (MS)/matrix spike
duplicate (MSD) analyses. These laboratory QC analyses are discussed in general below.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the most recent version of the Uniform Federal Policy-Quality
Assurance Project Plan (UFP QAPP) Part 1 (DoD 2005a), 2A (DoD 2012), and 2B (2005b), as well
as the DoD Quality Systems Manual (DoD 2013). As professional guidance for specific activities,
this procedure is not intended to obviate the need for professional judgment during unforeseen
circumstances. Deviations from this procedure while planning or executing planned activities must
be approved and documented by the following prime contractor representatives: the CTO Manager
and the Quality Assurance (QA) Manager or Technical Director. A Navy project representative
(i.e., Remedial Project Manager or QA Manager) shall also concur with any deviations.

3.	Definitions

3.1	Precision

Precision is the degree to which a set of observations or measurements of the same property,
obtained under similar conditions, conform to themselves. Precision is usually expressed as a
standard deviation, variance, or range, in either absolute or relative terms. Examples of QC measures
for precision include laboratory duplicates, laboratory triplicates, and matrix spike/matrix spike
duplicates.

3.2	Accuracy

Accuracy is the degree of agreement between an observed value and an accepted reference value.
Accuracy includes a combination of random error (precision) and systematic error (bias),
components which are due to sampling and analytical operations. Examples of QC measures for
accuracy include performance evaluation samples, matrix spikes, LCSs, and equipment blanks.

3.3	Matrix

A specific type of medium (e.g., surface water, drinking water), in which the analyte of interest may
be contained. Medium is a substance (e.g., air, water, soil), which serves as a carrier of the analytes
of interest (EPA 2010).

-------
NAVFAC Pacific ER Program
Laboratory QC Samples (Water, Soil)

Procedure Number:

Revision:

Page:

lll-A
May 2015
2 of 5

3.4	Method Blank

An analyte-free matrix (water, soil, etc.) subjected to the entire analytical process to demonstrate that
the analytical system itself does not introduce contamination.

3.5	Matrix Spike

A sample prepared by adding a known concentration of a target analyte to an aliquot of a specific
homogenized environmental sample for which an independent estimate of the target analyte
concentration is available. The MS is accompanied by an independent analysis of the unspiked
aliquot of the environmental sample. Spiked samples are used to determine the effect of the matrix
on a method's recovery efficiency.

3.6	Laboratory Control Samples and Blank Spikes

A sample of known composition prepared using reagent-free water or an inert solid that is spiked
with analytes of interest at the midpoint of the calibration curve or at the level of concern. It is
analyzed using the sample preparation, reagents, and analytical methods employed for regular
samples.

3.7	Surrogates

A pure substance with properties that mimic the analyte of interest (organics only). Surrogates are
typically brominated, fluorinated, or isotopically labeled compounds unlikely to be found in
environmental samples. These analytes are added to samples to evaluate analytical efficiency by
measuring recovery.

3.8	Internal Standards

A pure substance added to both samples and laboratory standards at a known concentration with the
purpose of providing a basis of comparison in the quantitation of analytes of interest. Internal
standards are primarily used to increase the accuracy and precision of analytical methods where the
primary source of variability is in sample preparation or sample injection on instrument.

4.	Responsibilities

The prime contractor's QA Manager or Technical Director, as well as QC coordinators are
responsible for ensuring that sample analytical activities during all CTOs are in compliance with this
procedure.

The CTO QC Coordinators and the Laboratory Manager are responsible for identifying instances of
non-compliance with this procedure and ensuring that future laboratory analytical activities are in
compliance with it.

5.	Procedures

Laboratory QC checks include all types of samples specified in the requested analytical methods,
such as the analysis of laboratory blank, duplicate, and MS samples. QC requirements are specified
in each analytical method and in Appendix B, Quality Control Requirements, and Appendix C,

Laboratory Control Sample (LCS) Control Limits and Requirements, of the Department of Defense
Quality Systems Manual for Environmental Laboratories Version 5.0 (or most current version)

-------
NAVFAC Pacific ER Program
Laboratory QC Samples (Water, Soil)

Procedure Number:

Revision:

Page:

lll-A
May 2015
3 of 5

(DoD QSM). Types of QC samples are discussed in general below. Detailed discussion and
minimum QA/QC requirements are presented in the DoD QSM (DoD 2013).

A comprehensive discussion of the minimum number of laboratory QC samples can be found in the
Uniform Federal Policy for Quality Assurance Project Plans, Part 2B, Quality Assurance/Quality
Control Compendium: Minimum QA/QC Activities (DoD 2005b). However, additional QA/QC
samples may be necessary based on the project quality objectives. Information pertaining to
laboratory QC samples shall be documented in Worksheet 28 Laboratory QC Samples Table of the
project UFP QAPP-style planning document.

5.1	Laboratory Blanks

Laboratory blank samples are analyzed to assess the degree to which laboratory contamination by
reagent or method preparation may have affected sample analytical results. At a minimum, one
laboratory blank will be analyzed per matrix per analytical method for each batch of at most
20 samples. In evaluating the blank results, all blank data are reviewed to identify any compounds
detected in the blanks. The laboratory shall be contacted to discuss detection of analytes in blank
samples only in the event of unusual contamination, but not for common laboratory contaminants at
low levels. The following compounds are considered to be common laboratory contaminants:
acetone, methylene chloride, 2-butanone, and common phthalate esters. The data for samples
analyzed during the same time period as the blank are then evaluated to identify the presence of any
contaminants found in the blanks. The presence of the blank contaminants found in associated
samples is then evaluated to avoid potential misinterpretation of actual sample constituents. Briefly,
as discussed in the data validation procedures, any analyte detected above the LOQ in both the
sample and the associated blank is qualified as not detected if the sample concentration is less than
five times the blank concentration (5/ rule). For common laboratory contaminants (methylene
chloride, acetone, 2-butanone, and common phthalate esters), a lOx rule applies.

5.2	Laboratory Replicates (Duplicates and Triplicates)

Replicates are analyzed to evaluate the reproducibility, or precision, of the analytical procedures for
a given sample. A replicate is two (duplicates) or three (triplicates) representative portions taken
from one homogeneous sample by the laboratory and analyzed in the same laboratory (DoD 2005a).
One duplicate sample is analyzed for each batch of twenty samples analyzed in a given matrix. Lab
triplicates are assigned by the field team and identified on the chain of custody. The identification of
a sample for lab triplicate analysis is typically selected from one of the field triplicates to allow for
the evaluation of total study error of the sampling and analysis process. Duplicate analyses are
normally performed on sample portions analyzed for inorganic constituents. For organic analyses,
duplicate analyses are performed on MS samples (Section 5.5 of this procedure).

5.3	Surrogates

Surrogate compounds must be added to all samples, standards, and blanks for all organic
chromatography methods except when the matrix precludes its use or when a surrogate is not
available. Poor surrogate recovery may indicate a problem with the sample composition and shall be
reported to the client whose sample produced the poor recovery. Surrogate compounds to be
included for organic analysis are specified in each analytical method.

-------
NAVFAC Pacific ER Program
Laboratory QC Samples (Water, Soil)

Procedure Number:

Revision:

Page:

lll-A
May 2015
4 of 5

5.4	Laboratory Control Samples and Blank Spikes

LCSs are used to demonstrate that the laboratory process for sample preparation and analysis is
under control.

Analytes selected for spiking of LCSs are usually the same compounds used to spike MS/MSD
samples and are representative target compounds. Control limits for LCS recoveries are provided in
Appendix C of DoD QSM. If no control limits for LCS recoveries are listed in Appendix C of the
DoD QSM for a given analyte, the laboratory's in-house derived control limits should be used.

For wet chemistry methods, a single spike of an appropriate control for each method may be used for
LCS analyses (i.e., cyanide, a control standard of sodium cyanide from a source other than that used
for calibration may be spiked into water samples and analyzed with the water samples). LCSs should
be analyzed at a frequency of one per batch of at most twenty samples analyzed of similar matrix.

5.5	Matrix Spikes/Matrix Spike Duplicates

MS analyses are conducted by the laboratory to assess the accuracy of specific analytical methods
and to provide information on the effect of the sample matrix on the analytical methodology. Spike
analyses are performed by adding compounds of known concentration to a sample, an unspiked
portion of which has previously been analyzed or is concurrently analyzed. The spiked analytes are
representative target compounds for each analytical method performed. The spiked sample results
are evaluated with the original sample results to evaluate any effects the matrix has on the analysis.
One MS is analyzed for each batch of at most 20 samples of similar matrix. Since MS samples only
provide information about the specific sample matrix used for the spike, MS analyses should be
performed for each type of matrix collected.

For the MSD, a separate aliquot of the sample is separately spiked and analyzed. As discussed in
Section 5.2, results of MSD analyses are expressed as a relative percent difference, which is
calculated by dividing the difference in concentration between the MSD and the MS sample analyses
by the arithmetic mean of their concentrations. One MSD analysis is required for at most each
20 samples of similar matrix.

Acceptance criteria for both the MS and the MSD are based on historic laboratory performance and
are laboratory-specific. As a general rule, the acceptance criteria should be no more stringent than
the LCS acceptance criteria.

It is important to note that the UFP QAPP Part 2B, QA/QC Compendium: Minimum QA/QC
Activities (DoD 2005b) states that for organic analysis, MS and MSDs are not considered a
minimum QC activity as long as surrogate spikes properly mimic the analytes of concern and can
identify matrix effects. Project quality objectives should be evaluated to determine if organic
MS/MSDs are useful for individual projects.

6. Records

Records of QC samples analyzed during ER Program CTO activities will be maintained on
laboratory bench sheets, raw data sheets, in the laboratory computerized data system, and on QC
summary forms, as requested. Analytical laboratories maintain records in accordance with their
quality assurance manual (QAM) as part of performing environmental analytical work under DoD.

-------
NAVFAC Pacific ER Program
Laboratory QC Samples (Water, Soil)

Procedure Number:

Revision:

Page:

lll-A
May 2015
5 of 5

Records shall be maintained in accordance with the analytical laboratory subcontract agreement
specifications or the laboratory-specific QAM, whichever is more stringent.

Applicable to laboratory personnel only.

8. References

Department of Defense, United States (DoD). 2005a. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

	. 2005b. Uniform Federal Policy for Quality Assurance Project Plans, Part 2B: Quality

Assurance/quality Control Compendium: Minimum QA/QC Activities. Final Version 1. DoD:
DTIC ADA 426957, EPA-505-B-04-900B. In conjunction with the U. S. Environmental
Protection Agency and the Department of Energy. Washington: Intergovernmental Data Quality
Task Force. March. On-line updates available at: http://www.epa.gov/swerffrr/pdf/-
qaqc_v 1 03 05 .pdf.

	. 2012. Uniform Federal Policy for Quality Assurance Project Plans, Part 2A: Optimized

UFP-QAPP Worksheets. Revision 1. March.

	. 2013. Department of Defense Quality Systems Manual for Environmental Laboratories.

Version 5.0. Final. Prepared by DoD Environmental Data Quality Workgroup and Department of
Energy Consolidated Audit Program Operations Team. July.

Environmental Protection Agency, United States (EPA). 2010. Environmental Monitoring and
Assessment Program: QA Glossary. November 8. On-line updates available at:
http://www.epa.gOv/emijulte/html/pubs/docs/resdocs/qa_terms.html#mm. Accessed 2015.

Procedure I-A-7, Analytical Data Validation Planning and Coordination.

7. Health and Safety

9. Attachments

None.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program

Procedure Number:

lll-B

Field QC Samples (Water, Soil)

Revision:

May 2015



Page:

1 of 6

Field QC Samples (Water, Soil)

1.	Purpose

This standard operating procedure describes the number and types of field quality control (QC)
samples that will be collected during United States Navy Environmental Restoration (ER) Program,
Naval Facilities Engineering Command (NAVFAC), Pacific site field work.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the most recent version of the Uniform Federal Policy-Quality
Assurance Project Plan Part 1 (DoD 2005a), 2A (DoD 2012), and 2B (2005b), as well as the DoD
Quality Systems Manual (DoD 2013). As professional guidance for specific activities, this procedure
is not intended to obviate the need for professional judgment during unforeseen circumstances.
Deviations from this procedure while planning or executing planned activities must be approved and
documented by the following prime contractor representatives: the Contract Task Order (CTO)
Manager and the Quality Assurance (QA) Manager or Technical Director, as well as QC
coordinators responsible for compliance with the procedure. A Navy project representative
(i.e., Remedial Project Manager or QA Manager) shall also concur with any deviations.

3.	Definitions

3.1	Trip Blank

Trip blanks are samples that originate from organic-free water (e.g., ASTM Type II water, high
performance liquid chromatography grade water, etc.) prepared by the laboratory, shipped to the
sampling site, and returned to the laboratory with samples to be analyzed for volatile organic
compounds (VOCs). Trip blanks are analyzed to assess whether contamination was introduced
during sample shipment (DoD 2005a). Trip blanks are prepared using the same sample container
(typically a 40 ml VOA vial) as that used to collect field samples.

3.2	Equipment Blank Samples

An equipment blank (i.e., "decontamination rinsate," or "equipment rinsate") sample consists of a
sample of water free of measurable contaminants poured over or through decontaminated field
sampling equipment that is considered ready to collect or process an additional sample. Equipment
blanks are to be collected from non-dedicated sampling equipment to assess the adequacy of the
decontamination process.

3.3	Field Blanks

A blank used to provide information about contaminants that may be introduced during sample
collection, storage, and transport. It can also be a clean sample carried to the sampling site, exposed
to sampling conditions, transported to the laboratory, and treated as an environmental sample.

-------
NAVFAC Pacific ER Program
Field QC Samples (Water, Soil)

Procedure Number:

Revision:

Page:

lll-B
May 2015
2 of 6

3.4	Field Duplicate

A generic term for two field samples taken at the same time in approximately the same location is
referred to as a field duplicate. The location of the duplicate (distance and direction from primary
sample) should be specified in the project planning documents. They are intended to represent the
same population and are taken through all steps of the analytical procedure in an identical manner
and provide precision information for the data collection activity. There are two categories of field
duplicate samples defined by the collection method: co-located field duplicates and subsample field
duplicates. Co-located field duplicates are two or more independent samples collected from
side-by-side locations at the same point in time and space so as to be considered identical.
Co-located samples are collected from adjacent locations or liners (e.g., laterally or vertically, in
separate containers), or water samples collected from the same well at the same time that have not
been homogenized. Subsample field duplicates samples are obtained from one sample collection at
one sample location.

3.5	Field Replicates

Two or more field replicates are used with incremental sampling approaches to statistically evaluate
the sampling precision or error for each decision unit (DU). The location of the replicates (distance
and direction from primary sample) and the number of DUs with replicates should be specified in the
project planning documents. Increments for replicate samples are collected from completely separate
locations (i.e., separate systematic random or stratified random grid). Triplicate samples
(i.e., primary incremental sample plus two replicates) are required for incremental sampling and are
more useful than just duplicates for statistical evaluation. The replicate samples are collected,
prepared, and analyzed in the same manner as carried out for the primary sample.

3.6	Temperature Indicators (Blanks)

A temperature indicator sample is often referred to as a temperature blank, but it is not analyzed nor
does it measure introduced contamination. It may be a small sample bottle or VOA vial filled with
distilled water that is placed in each shipping container to evaluate if samples were adequately
cooled during sample shipment.

3.7	Source Water

Source water is water free from measurable contaminants that is used as the final decontamination
rinse water.

4. Responsibilities

The prime contractor CTO Manager and QA Manager or Technical Director are responsible for
ensuring that field QC samples are collected and analyzed according to this procedure. The CTO
Manager is responsible for ensuring that all personnel involved in sampling or testing shall have the
appropriate education, experience, and training to perform their assigned tasks as specified in Chief
of Naval Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

The prime contractor QC Coordinator is responsible for determining the QC sample requirements.

The Laboratory Manager is responsible for ensuring that field QC samples are analyzed according to
the specifications of the project statement of work and the analytical methods used.

-------
NAVFAC Pacific ER Program
Field QC Samples (Water, Soil)

Procedure Number:

Revision:

Page:

lll-B
May 2015
3 of 6

The Field Manager is responsible for ensuring that all project field staff follow these procedures.

Field sampling personnel are responsible for the implementation of this procedure.

5. Procedures

Field QC checks may include submission of trip blank, equipment blank, field blank, duplicate,
triplicate, and temperature indicator (blank) samples to the laboratory. Types of field QC samples are
discussed in general below. Table III-B-1 identifies the minimum frequency at which field QC
samples should be collected, with the actual frequency to be determined by the individual project
needs. For additional information on field QC frequency, see the State of Hawaii Department of
Health 2009 Technical Guidance Manual for the Implementation of the Hawaii State Contingency
Plan.

A comprehensive discussion of the minimum types and numbers of field QC samples can be found

in the Uniform Federal Policy for Quality Assurance Project Plans, Part 2B, Quality
Assurance/Quality Control Compendium: Minimum QA/QC Activities (DoD 2005).

Table lll-B-1: Field QC Samples per Sampling Event



Minimum QC Sample Frequency

Type of Sample

Metals

Organic

Trip blank (for volatiles only)

N/A

1/analytical method/cooler

Equipment blank

5%

5%

Field blank

1/decontamination water source/event a/for all analytes

Field replicates b

10%

10%

Temperature Indicator (blank)

1/shipping container

%	percent

N/A not applicable

a A sampling event is considered to be from the time sampling personnel arrive at a site until they leave for more than a week.

The use of controlled-lot source water makes one sample per lot, rather than per event, an option.
b To the extent practical, field replicates should be collected from the same locations as the samples designated for a
laboratory matrix spike/matrix spike duplicate (organic analysis) where applicable, or from the sample used as a laboratory
duplicate (inorganic analysis).

5.1 Trip Blanks

The laboratory prepares trip blanks using organic-free water, and then sends them to the field. The
laboratory shall place trip blanks in sample coolers prior to transport to the site so that they
accompany the samples throughout the sample collection/handling/transport process. Once prepared,
trip blanks should not be opened until they reach the laboratory. One set of two 40-milliliter vials per
volatile analysis forms a trip blank and accompanies each cooler containing samples to be analyzed
for volatiles. Trip blanks are only analyzed for volatiles. Results of trip blank analyses are used to
assess whether samples have been contaminated by volatiles during sample handling and transport to
the laboratory.

Trip blanks are not typically associated with tissue samples; however, project-specific quality
objectives shall determine if trip blanks for tissue samples are required.

-------
NAVFAC Pacific ER Program
Field QC Samples (Water, Soil)

Procedure Number:

Revision:

Page:

lll-B
May 2015
4 of 6

5.2	Equipment Blank Samples

Collect equipment blank samples by pumping the source water over and/or through the
decontaminated sampling equipment. Collect this runoff water into the sample containers directly or
with the use of a funnel, if necessary. The source water may be pumped or poured by tipping the jug
of water upside down over the equipment. Results of equipment blank samples are used to evaluate
whether equipment decontamination was effective.

At a minimum, equipment blank samples should be collected at a rate of 5 percent of the total
samples planned for collection for each sampling technique used. This rate may be adjusted
depending on the nature of the investigation (site inspection, remedial investigation, remedial site
evaluation, long-term monitoring) and the associated project quality objectives (PQOs). Equipment
blank samples will be analyzed for the same parameters as the samples collected with that particular
equipment. If analytes pertinent to the project are found in the equipment blanks, the frequency of
equipment blank samples may be increased after decontamination procedures have been modified to
further evaluate the effectiveness of the decontamination procedure.

When disposable or dedicated sampling equipment is used, equipment blank samples do not need to
be collected.

Sampling devices (e.g., gloved hands, dip nets, or traps) used for collection of tissue samples are
generally non-intrusive into the organisms collected, so equipment blank samples will not be
collected as long as the devices have been properly cleaned following Procedure I-F, Equipment
Decontamination, and appear clean.

5.3	Field Blanks

Field blanks, consisting of samples of the source water used as the final decontamination rinse water,
will be collected on site by field personnel by pouring the source water into sample containers and
then analyzed to assess whether contaminants may have been introduced during sample collection,
storage, and transport.

The final decontamination rinse water source (the field blank source water) and equipment blank
source water should all be from the same purified water source. Tap water used for steam cleaning
augers or used in the initial decontamination buckets need not be collected and analyzed as a field
blank since augers typically do not touch the actual samples and the final decontamination rinse
water should be from a purified source.

Field blanks should be collected at a minimum frequency of one per sampling event per each source
of water. A sampling event is considered to be from the time sampling personnel arrive at a site until
they leave for more than a week. Field blanks will be analyzed for the same parameters as the
samples collected during the period that the water sources are being used for decontamination.
Additional field blanks may be required based on PQOs.

5.4	Field Duplicates

Field duplicates consist of either co-located or subsampled samples. Field duplicates for ground
water and surface water samples are generally considered to be co-located samples. Soil duplicate
samples may be homogenized and subsampled in the field (or at the laboratory) to form an original

-------
NAVFAC Pacific ER Program
Field QC Samples (Water, Soil)

Procedure Number:

Revision:

Page:

lll-B
May 2015
5 of 6

and duplicate sample, or may be an additional volume of sample collected in a separate sample
container to form a co-located sample.

The interpretation of co-located duplicate data may be more complex than subsample duplicate data
because of the number of variables associated with the results of this type of duplicate sample.
Duplicate soil samples for VOC analysis shall always be co-located (i.e., not homogenized or
otherwise processed or subsampled). Duplicates will be analyzed for the same analytical parameters
as their associated original sample. Collection of both co-located and subsampled versions of the
same sample may be performed to aid in approximating sampling and analysis error.

Field duplicates for biological tissue samples will consist of subsamples of the original sample.
Twice the required volume of organisms for one sample will be collected and placed into one food-
grade, self-sealing bag. The sample will later be homogenized in the laboratory and subsampled,
producing an original and a duplicate sample. Tissue duplicate samples will be analyzed for the same
analytical parameters as their associated original samples.

5.5	Field Replicates

Field replicates are completely separate incremental replicate samples (collected from a set of
systematic random or stratified random locations within the DU that are different from those used for
the primary incremental samples). A different random starting location is determined for each
replicate collected in the selected DU. Field replicates are typically collected in sets of three (the
primary sample and two replicate samples) to produce a triplicate.

Replicate sample increments are collected from the same sampling grid established through the DU
for the primary incremental sample, though at different systematic random locations than initially
used. The replicate increments should not be collected from the same points or co-located with those
used for the primary incremental sample. Replicate samples are sent to the laboratory as "blind"
samples, meaning the laboratory does not know they represent replicate samples of the primary
incremental sample.

5.6	Temperature Indicators (Blanks)

Temperature indicators (blanks) may be prepared in the lab or field by filling a small sample bottle
or VOA vial with distilled water and sealing the container. One temperature indicator sample should
be placed in each sample cooler or shipping container. Upon arrival at the laboratory, the
temperature of the bottle is measured to determine if samples were adequately cooled during the
shipment.

6. Records

Records of QC samples analyzed during ER Program CTO activities will be maintained on
laboratory bench sheets, raw data sheets, in the laboratory computerized data system, and on QC
summary forms, as requested. Analytical laboratories maintain records in accordance with their
quality assurance manual (QAM) as part of performing environmental analytical work under DoD.
Records shall be maintained in accordance with the analytical laboratory subcontract agreement
specifications or the laboratory-specific QAM, whichever is more stringent.

-------
NAVFAC Pacific ER Program
Field QC Samples (Water, Soil)

Procedure Number:

Revision:

Page:

lll-B
May 2015
6 of 6

7.	Health and Safety

Field personnel shall perform work in accordance with the current (or as contractually obligated)

United States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1

(USACE 2008) and site-specific health and safety plan.

8.	References

Department of Defense, United States (DoD). 2005a. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

	. 2005b. Uniform Federal Policy for Quality Assurance Project Plans, Part 2B: Quality

Assurance/quality Control Compendium: Minimum QA/QC Activities. Final Version 1. DoD:
DTIC ADA 426957, EPA-505-B-04-900B. In conjunction with the U. S. Environmental
Protection Agency and the Department of Energy. Washington: Intergovernmental Data Quality
Task Force. March. On-line updates available at: http://www.epa.gov/swerffirr/pdf/-
qaqc_v 1 03 05 .pdf.

	. 2012. Uniform Federal Policy for Quality Assurance Project Plans, Part 2A: Optimized

UFP-QAPP Worksheets. Revision 1. March.

	. 2013. Department of Defense Quality Systems Manual for Environmental Laboratories.

Version 5.0. Draft Final. Prepared by DoD Environmental Data Quality Workgroup and
Department of Energy Consolidated Audit Program Operations Team. July.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure I-F, Equipment Decontamination.

Procedure III-E, Record Keeping, Sample Labeling, and Chain-of-Custody.

9.	Attachments

None.

-------
NAVFAC Pacific ER Program
Logbooks

Procedure Number:

Revision:

Page:

ili-D
May 2015
1 of 7

Logbooks

1.	Purpose

This standard operating procedure describes the activities and responsibilities pertaining to the
identification, use, and control of logbooks and associated field data records for use by United States
Navy Environmental Restoration (ER) Program, Naval Facilities Engineering Command
(NAVFAC), Pacific personnel.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management approved professional guidance for the ER Program and
is consistent with protocol in the most recent version of the Uniform Federal Policy-Quality
Assurance Project Plan Appendix A. Section 1.4 Field Documentation SOPs (DoD 2005). As
professional guidance for specific activities, this procedure is not intended to obviate the need for
professional judgment during unforeseen circumstances. Deviations from this procedure while
planning or executing planned activities must be approved and documented by the following prime
contractor representatives: the Contract Task Order (CTO) Manager and the Quality Assurance
Manager or Technical Director. A Navy project representative (i.e., Remedial Project Manager or
QA Manager) shall also concur with any deviations.

3.	Definitions

3.1	Logbook

A logbook is a bound field notebook with consecutively numbered, water-repellent pages that is
clearly identified with the name of the relevant activity, the person assigned responsibility for
maintenance of the logbook, and the beginning and ending dates of the entries.

3.2	Data Form

A data form is a predetermined format used for recording field data that may become, by reference, a
part of the logbook (e.g., soil boring logs, trenching logs, surface soil sampling logs, groundwater
sample logs, and well construction logs are data forms).

4.	Responsibilities

The prime contractor CTO Manager or delegate is responsible for determining which team members
shall record information in field logbooks and for obtaining and maintaining control of the required
logbooks. The CTO Manager shall review the field logbook on at least a monthly basis. The CTO
Manager or designee is responsible for reviewing logbook entries to determine compliance with this
procedure and to ensure that the entries meet the project requirements.

A knowledgeable individual such as the Field Manager, CTO Manager, or quality control (QC)
Supervisor shall perform a technical review of each logbook at a frequency commensurate with the
level of activity (weekly is suggested, or, at a minimum, monthly). Document these reviews by the

-------
NAVFAC Pacific ER Program
Logbooks

Procedure Number:

Revision:

Page:

ili-D
May 2015
2 of 7

dated signature of the reviewer on the last page or page immediately following the material
reviewed.

The Field Manager is responsible for ensuring that all project field staff follow these procedures and
that the logbook is completed properly and daily. The Field Manager is also responsible for
submitting copies to the CTO Manager, who is responsible for filing them and submitting a copy to
the Navy (if required by the CTO Statement of Work).

The logbook user is responsible for recording pertinent data into the logbook to satisfy project
requirements and for attesting to the accuracy of the entries by dated signature. The logbook user is
also responsible for safeguarding the logbook while having custody of it.

Field personnel are responsible for the implementation of this procedure.

All NAVFAC Pacific ER Program field personnel are responsible for complying with Chief of Naval
Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

5. Procedure

The field logbook serves as the primary record of field activities. Make entries chronologically and
in sufficient detail to allow the writer or a knowledgeable reviewer to reconstruct the applicable
events. Store the logbook in a clean location and use it only when outer gloves used for personal
protective equipment (PPE) have been removed.

Individual data forms may be generated to provide systematic data collection documentation. Entries
on these forms shall meet the same requirements as entries in the logbook and shall be referenced in
the applicable logbook entry. Individual data forms shall reference the applicable logbook and page
number. At a minimum, include names of all samples collected in the logbook even if they are
recorded elsewhere.

Enter field descriptions and observations into the logbook, as described in Attachment III-D-1, using
indelible black ink.

Typical information to be entered includes the following:

Dates (month/day/year) and times (military) of all onsite activities and entries made in
logbooks/forms

Site name, and description

Site location by longitude and latitude, if known

Weather conditions, including estimated temperature and relative humidity
Fieldwork documentation, including site entry and exit times

Descriptions of, and rationale for, approved deviations from the work plan or field sampling
plan

Field instrumentation readings

Names, job functions, and organizational affiliations of personnel on-site

-------
NAVFAC Pacific ER Program
Logbooks

Procedure Number:

Revision:

Page:

ili-D
May 2015
3 of 7

Photograph references

Site sketches and diagrams made on-site

Identification and description of sample morphology, collection locations and sample
numbers as described in Procedure I-A-8, Sample Naming

Sample collection information, including dates (month/day/year) and times (military) of
sample collections, sample collection methods and devices, station location numbers, sample
collection depths/heights, sample preservation information, sample pH (if applicable),
analysis requested (analytical groups), etc., as well as chain-of-custody (COC) information
such as sample identification numbers cross-referenced to COC sample numbers

Sample naming convention

Field QC sample information

Site observations, field descriptions, equipment used, and field activities accomplished to
reconstruct field operations

Meeting information

Important times and dates of telephone conversations, correspondence, or deliverables
Field calculations
PPE level
Calibration records

Contractor and subcontractor information (address, names of personnel, job functions,
organizational affiliations, contract number, contract name, and work assignment number)

Equipment decontamination procedures and effectiveness

Laboratories receiving samples and shipping information, such as carrier, shipment time,
number of sample containers shipped, and analyses requested

User signatures

The logbook shall reference data maintained in other logs, forms, etc. Correct entry errors by
drawing a single line through the incorrect entry, then initialing and dating this change. Enter an
explanation for the correction if the correction is more than for a mistake.

At least at the end of each day, the person making the entry shall sign or initial each entry or group
of entries.

Enter logbook page numbers on each page to facilitate identification of photocopies.

If a person's initials are used for identification, or if uncommon acronyms are used, identify these on
a page at the beginning of the logbook.

At least weekly and preferably daily, the preparer shall photocopy (or scan) and retain the pages
completed during that session for backup. This will prevent loss of a large amount of information if
the logbook is lost.

-------
NAVFAC Pacific ER Program
Logbooks

Procedure Number:

Revision:

Page:

ili-D
May 2015
4 of 7

6. Records

Retain the field logbook as a permanent project record. If a particular CTO requires submittal of
photocopies of logbooks, perform this as required.

Store the logbook in a clean location to keep it clean and use it only when outer gloves used for PPE

have been removed.

8. References

Department of Defense, United States (DoD). 2005a. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

Procedure I-A-8, Sample Naming.

7. Health and Safety

9. Attachments

Attachment III-D-1: Description of Logbook Entries

-------
Attachment lll-D-1
Description of Logbook Entries

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Logbooks

Procedure Number: ili-D
Revision: May 2015
Page: 7 of 7

Logbook entries shall be consistent with Section A. 1.4 Field Documentation SOPs of the
UFP-QAPP Manual (DoD 2005) and contain the following information, as applicable, for each
activity recorded. Some of these details may be entered on data forms, as described previously.

Name of Activity

For example, Asbestos Bulk Sampling, Charcoal Canister Sampling,
Aquifer Testing.

Task Team Members and
Equipment

Name all members on the field team involved in the specified activity.
List equipment used by serial number or other unique identification,
including calibration information.

Activity Location

Indicate location of sampling area as indicated in the field sampling
plan.

Weather

Indicate general weather and precipitation conditions.

Level of PPE

Record the level of PPE (e.g., Level D).

Methods

Indicate method or procedure number employed for the activity.

Sample Numbers

Indicate the unique numbers associated with the physical samples.
Identify QC samples.

Sample Type
and Volume

Indicate the medium, container type, preservative, and the volume for
each sample.

Time and Date

Record the time and date when the activity was performed
(e.g., 0830/08/OCT/89). Use the 24-hour clock for recording the time
and two digits for recording the day of the month and the year.

Analyses

Indicate the appropriate code for analyses to be performed on each
sample, as specified in the WP.

Field Measurements

Indicate measurements and field instrument readings taken during the
activity.

Chain of Custody
and Distribution

Indicate chain-of-custody for each sample collected and indicate to
whom the samples are transferred and the destination.

References

If appropriate, indicate references to other logs or forms, drawings, or
photographs employed in the activity.

Narrative (including time
and location)

Create a factual, chronological record of the team's activities
throughout the day including the time and location of each activity.
Include descriptions of general problems encountered and their
resolution. Provide the names and affiliations of non-field team
personnel who visit the site, request changes in activity, impact the
work schedule, request information, or observe team activities. Record
any visual or other observations relevant to the activity, the
contamination source, or the sample itself.

It should be emphasized that logbook entries are for recording data and
chronologies of events. The logbook author must include observations
and descriptive notations, taking care to be objective and recording no
opinions or subjective comments unless appropriate.

Recorded by

Include the signature of the individual responsible for the entries
contained in the logbook and referenced forms.

Checked by

Include the signature of the individual who performs the review of the
completed entries.

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
1 of 26

Record Keeping, Sample Labeling, and Chain-Of-Custody

1.	Purpose

The purpose of this standard operating procedure is to establish standard protocols for all United
States (U.S.) Navy Environmental Restoration (ER) Program, Naval Facilities Engineering
Command (NAVFAC), Pacific field personnel for use in maintaining field and sampling activity
records, writing sample logs, labeling samples, ensuring that proper sample custody procedures are
used, and completing chain-of-custody/analytical request forms.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the most recent version of the Uniform Federal Policy-Quality
Assurance Project Plan (UFP QAPP) Part 1 (DoD 2005a), 2A (DoD 2012), and 2B (2005b), as well
as the DoD Quality Systems Manual (DoD 2013). As professional guidance for specific activities,
this procedure is not intended to obviate the need for professional judgment during unforeseen
circumstances. Deviations from this procedure while planning or executing planned activities must
be approved and documented by the following prime contractor representatives: the CTO Manager
and the Quality Assurance (QA) Manager or Technical Director. A Navy project representative
(i.e., Remedial Project Manager or QA Manager) shall also concur with any deviations.

3.	Definitions

3.1	Logbook

A logbook is a bound field notebook with consecutively numbered, water-repellent pages that is
clearly identified with the name of the relevant activity, the person responsible for maintenance of
the logbook, and the beginning and ending dates of the entries.

3.2	Chain-of-Custody

Chain-of-custody (COC) is documentation of the process of custody control. Custody control
includes possession of a sample from the time of its collection in the field to its receipt by the
analytical laboratory, and through analysis and storage prior to disposal.

4.	Responsibilities

The prime contractor CTO Manager is responsible for determining which team members shall record
information in the field logbook and for checking sample logbooks and COC forms to ensure
compliance with these procedures. The CTO Manager shall review COC forms on a monthly basis at
a minimum.

The prime contractor CTO Manager and QA Manager or Technical Director are responsible for
evaluating project compliance with the Project Procedures Manual. The QA Manager or Technical
Director is responsible for ensuring overall compliance with this procedure.

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
2 of 26

The Laboratory Project Manager or Sample Control Department Manager is responsible for
reporting any sample documentation or COC problems to the CTO Manager or CTO Laboratory
Coordinator within 24 hours of sample receipt.

The Field Manager is responsible for ensuring that all field personnel follow these procedures. The
CTO Laboratory Coordinator is responsible for verifying that the COC/analytical request forms have
been completed properly and match the sampling and analytical plan. The CTO Manager or CTO
Laboratory Coordinator is responsible for notifying the laboratory, data managers, and data
validators in writing if analytical request changes are required as a corrective action. These small
changes are different from change orders, which involve changes to the scope of the subcontract with
the laboratory and must be made in accordance with a respective contract (e.g., Comprehensive
Long-Term Environmental Action Navy, remedial action contract).

NAVFAC Pacific ER Program field personnel are responsible for following these procedures while
conducting sampling activities. Field personnel are responsible for recording pertinent data into the
logbook to satisfy project requirements and for attesting to the accuracy of the entries by dated
signature. All NAVFAC Pacific ER Program field personnel are responsible for complying with
Chief ofNaval Operations Instruction 5090.1, under Specific Training Requirements (DON 2014).

5. Procedures

This procedure provides standards for documenting field activities, labeling the samples,
documenting sample custody, and completing COC/analytical request forms. The standards
presented in this section shall be followed to ensure that samples collected are maintained for their
intended purpose and that the conditions encountered during field activities are documented.

5.1	Recordkeeping

The field logbook serves as the primary record of field activities. Make entries chronologically and
in sufficient detail to allow the writer or a knowledgeable reviewer to reconstruct each day's events.
Field logs such as soil boring logs and groundwater sampling logs will also be used. These
procedures are described in Procedure III-D, Logbooks.

5.2	Sample Labeling

Affix a sample label with adhesive backing to each individual sample container with the exception of
pre-tared containers. Record the following information with a waterproof marker (ballpoint pen for
containers for volatile analyses) on each label:

Project name or number (optional)

COC sample number
Date and time of collection
Sampler's initials
Matrix (optional)

Sample preservatives (if applicable)

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
3 of 26

Analysis to be performed on sample (This shall be identified by the method number or name
identified in the subcontract with the laboratory)

Indicate if sample is to be used as the matrix spike (MS)/matrix spike duplicate (MSD) or
laboratory triplicate sample

With the exception of sample containers with pre-tared labels, place clear tape over each label
(preferably prior to sampling) to prevent the labels from tearing off, falling off, or being smeared,
and to prevent loss of information on the label.

These labels may be obtained from the analytical laboratory or printed from a computer file onto
adhesive labels.

For volatile soil organic analyses (VOA), labels are not to be affixed to vials that are pre-tared by the
laboratory. Instead, on each of the VOA vials in the sample set (typically three per sample), mark the
sample COC Sample identification (ID) on the vial in ballpoint pen. Then wrap the vials together in
bubble wrap and place one sample label on the bubble wrap and cover with tape. It is imperative that
the COC Sample ID be clearly marked on each vial as this will help prevent laboratory error if the
vials are inadvertently separated after removal from the bubble wrap.

5.3 Custody Procedures

For samples intended for chemical analysis, sample custody procedures shall be followed through
collection, transfer, analysis, and disposal to ensure that the integrity of the samples is maintained.
Maintain custody of samples in accordance with the U.S. Environmental Protection Agency (EPA)
COC guidelines prescribed in U.S. Environmental Protection Agency (EPA) NEIC Policies and
Procedures, National Enforcement Investigations Center, Denver, Colorado, revised August 1991
(EPA 1978); EPA RCRA Ground Water Monitoring Technical Enforcement Guidance Document
(TEGD), Guidance for Conducting Remedial Investigations and Feasibility Studies Under CERCLA
(EPA OSWER Directive 9355 3-01) (EPA 1988, Appendix 2 of the Technical Guidance Manual for
Solid Waste Water Quality Assessment Test (SWAT) Proposals and Reports (Cal/EPA 1988), and
Test Methods for Evaluating Solid Waste (EPA 2007). A description of sample custody procedures is
provided below.

5.3.1 Sample Collection Custody Procedures

According to the EPA guidelines, a sample is considered to be in custody if one of the following
conditions is met:

It is in one's actual physical possession or view

It is in one's physical possession and has not been tampered with (i.e., it is under lock or
official seal)

It is retained in a secured area with restricted access

It is placed in a container and secured with an official seal such that the sample cannot be
reached without breaking the seal

Place custody seals on sample containers (on bubble wrap for pre-tared containers) immediately after
sample collection and on shipping coolers if the cooler is to be removed from the sampler's custody.

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
4 of 26

Place custody seals in such a manner that they must be broken to open the containers or coolers.
Label the custody seals with the following information:

Sampler's name or initials

Date and time that the sample/cooler was sealed

These seals are designed to enable detection of sample tampering. An example of a custody seal is
shown in Attachment III-E-1.

Field personnel shall also log individual samples onto COC forms (carbon copy or computer
generated) when a sample is collected or just prior to shipping. These forms may also serve as the
request for analyses. Procedures for completing these forms are discussed in Section 5.4, indicating
sample identification number, matrix, date and time of collection, number of containers, analytical
methods to be performed on the sample, and preservatives added (if any). The samplers will also
sign the COC form signifying that they were the personnel who collected the samples. The COC
form shall accompany the samples from the field to the laboratory. When a cooler is ready for
shipment to the analytical laboratory, the person delivering the samples for transport will sign and
indicate the date and time on the accompanying COC form. One copy of the COC form will be
retained by the sampler and the remaining copies of the COC form shall be placed inside a self-
sealing bag and taped to the inside of the cooler. Each cooler must be associated with a unique COC
form. Whenever a transfer of custody takes place, both parties shall sign and date the accompanying
carbon copy COC forms, and the individual relinquishing the samples shall retain a copy of each
form. One exception is when the samples are shipped; the delivery service personnel will not sign or
receive a copy because they do not open the coolers. The laboratory shall attach copies of the
completed COC forms to the reports containing the results of the analytical tests. An example COC
form is provided in Attachment III-E-2.

5.3.2 Laboratory Custody Procedures

The following custody procedures are to be followed by an independent laboratory receiving samples
for chemical analysis; the procedures in their Naval Facilities Engineering and Expeditionary
Warfare Center-evaluated Laboratory Quality Assurance Plan must follow these same procedures. A
designated sample custodian shall take custody of all samples upon their arrival at the analytical
laboratory. The custodian shall inspect all sample labels and COC forms to ensure that the
information is consistent, and that each is properly completed. The custodian will also measure the
temperature of the temperature blank in the coolers upon arrival using either a National Institute for
Standards and Technology calibrated thermometer or an infra-red temperature gun. The custodian
shall note the condition of the samples including:

If the samples show signs of damage or tampering
If the containers are broken or leaking
If headspace is present in sample vials

Proper preservation of samples (made by pH measurement, except volatile organic
compounds (VOCs) and purgeable total petroleum hydrocarbons (TPH) and temperature).
The pH of VOC and purgeable TPH samples will be checked by the laboratory analyst after
the sample aliquot has been removed from the vial for analysis.

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
5 of 26

If any sample holding times have been exceeded

All of the above information shall be documented on a sample receipt sheet by the custodian.

Discrepancies or improper preservation shall be noted by the laboratory as an out-of-control event
and shall be documented on an out-of-control form with corrective action taken. The out-of-control
form shall be signed and dated by the sample control custodian and any other persons responsible for
corrective action. An example of an out-of-control form is included as Attachment III-E-4.

The custodian shall then assign a unique laboratory number to each sample and distribute the
samples to secured storage areas maintained at 4 degrees Celsius (soil samples for VOC analysis are
to be stored in a frozen state until analysis). The unique laboratory number for each sample, the COC
sample number, the client name, date and time received, analysis due date, and storage shall also be
manually logged onto a sample receipt record and later entered into the laboratory's computerized
data management system. The custodian shall sign the shipping bill and maintain a copy.

Laboratory personnel shall be responsible for the care and custody of samples from the time of their
receipt at the laboratory through their exhaustion or disposal. Samples should be logged in and out
on internal laboratory COC forms each time they are removed from storage for extraction or
analysis.

5.4 Completing COC/Analytical Request Forms

COC form/analytical request form completion procedures are crucial in properly transferring the
custody and responsibility of samples from field personnel to the laboratory. This form is important
for accurately and concisely requesting analyses for each sample; it is essentially a release order
from the analysis subcontract.

Attachment III-E-2 is an example of a generic COC/analytical request form that may be used by field
personnel. Multiple copies may be tailored to each project so that much of the information described
below need not be handwritten each time. Attachment III-E-3 is an example of a completed
site-specific COC/analytical request form, with box numbers identified and discussed in text below.

Box 1 Project Manager: This name shall be the name that will appear on the report. Do not
write the name of the Project Coordinator or point of contact for the project instead
of the CTO manager.

Project Name: Write the project name as it is to appear on the report.

Project Number: Write the project number as it is to appear on the report. It shall
include the project number and task number. Also include the laboratory subcontract
number.

Box 2 Bill to: List the name and address of the person/company to bill only if it is not in
the subcontract with the laboratory.

Box 3 Sample Disposal Instructions: These instructions will be stated in the Master Service
Agreement or each CTO statement of work with each laboratory.

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
6 of 26

Shipment Method: State the method of shipment (e.g., hand carry; air courier via
FED EX, AIR BORNE, or DHL).

Comment: This area shall be used by the field team to communicate observations,
potential hazards, or limitations that may have occurred in the field or additional
information regarding analysis (e.g., a specific metals list, samples expected to
contain high analyte concentrations).

Box 4 Cooler Number: This will be written on the inside or outside of the cooler and shall

be included on the COC. Some laboratories attach this number to the trip blank
identification, which helps track volatile organic analysis samples. If a number is not
on the cooler, field personnel shall assign a number, write it on the cooler, and write
it on the COC.

QC Level: Enter the reporting/QC requirements (e.g., Full Data Package, Summary
Data Package).

Turn around time (TAT): TAT will be determined by a sample delivery group
(SDG), which may be formed over a 14-day period, not to exceed 20 samples. Once
the SDG has been completed, standard TAT is 21 calendar days from receipt of the
last sample in the SDG. Entering NORMAL or STANDARD in this field will be
acceptable. If quicker TAT is required, it shall be in the subcontract with the
laboratory and reiterated on each COC to remind the laboratory.

Box 5 Type of containers: Write the type of container used (e.g., 1 liter glass amber, for a
given parameter in that column).

Preservatives: Field personnel must indicate on the COC the correct preservative
used for the analysis requested. Indicate the pH of the sample (if tested) in case there
are buffering conditions found in the sample matrix.

Box 6 COC sample number: This is typically a five-character alpha-numeric identifier used

by the contractor to identify samples. The use of this identifier is important since the
labs are restricted to the number of characters they are able to use. See Procedure
I-A-8, Sample Naming.

Description (sample identification): This name will be determined by the location
and description of the sample, as described in Procedure I-A-8, Sample Naming.
This sample identification should not be submitted to the laboratory, but should be
left blank. If a computer COC version is used, the sample identification can be input,
but printed with this block black. A cross-referenced list of COC Sample Number
and sample identification must be maintained separately.

Identify if sample requires laboratory subsampling.

Date Collected: Record the collection date to track the holding time of the sample.
Note: For trip blanks, record the date it was placed in company with samples.

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
7 of 26

Box 7

Box 8

Box 9

Box 10

Time Collected: When collecting samples, record the time the sample is first
collected. Use of the 24-hour military clock will avoid a.m. or p.m. designations
(e.g., 1815 instead of 6:15 p.m.). Record local time; the laboratory is responsible for
calculating holding times to local time.

Lab Identification: This is for laboratory use only.

Matrix and QC: Identify the matrix (e.g., water, soil, air, tissue, fresh water
sediment, marine sediment, or product). If a sample is expected to contain high
analyte concentrations (e.g., a tank bottom sludge or distinct product layer), notify
the laboratory in the comment section. Mark an "X" for the sample(s) that have extra
volume for laboratory QC matrix spike/matrix spike duplicate (MS/MSD) or
laboratory triplicate purposes. The sample provided for MS/MSD purposes is usually
a field duplicate.

Analytical Parameters: Enter the parameter by descriptor and the method number
desired (e.g. benzene, toluene, ethylbenzene, and xylenes 8260B, polynuclear
aromatic hydrocarbons 8270C, etc.). Whenever practicable, list the parameters as
they appear in the laboratory subcontract to maintain consistency and avoid
confusion.

If the COC does not have a specific box for number of sample containers, use the
boxes below the analytical parameter, to indicate the number of containers collected
for each parameter.

Sampler's Signature: The person who collected samples must sign here.

Relinquished By: The person who turned over the custody of the samples to a second
party other than an express mail carrier, such as FEDEX, must sign here.

Received By: Typically, a representative of the receiving laboratory signs here. Or, a
field crew member who delivered the samples in person from the field to the
laboratory might sign here. A courier, such as Federal Express, does not sign here
because they do not open the coolers. It must also be used by the prime contracting
laboratory when samples are to be sent to a subcontractor.

Relinquished By: In the case of subcontracting, the primary laboratory will sign the
Relinquished By space and fill out an additional COC to accompany the samples
being subcontracted.

Received By (Laboratory): This space is for the final destination (e.g., at a
subcontracted laboratory).

Lab Number and Questions: This box is to be filled in by the laboratory only.

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
8 of 26

Box 11 Control Number: This number is the "COC" followed by the first contractor
identification number in that cooler, or contained on that COC. This control number
must be unique (i.e., never used twice). Record the date the COC is completed. It
should be the same date the samples are collected.

Box 12 Total No. of Containers/row: Sum the number of containers in that row.

Box 13 Total No. of Containers/column: Sum the number of containers in that column.

Because COC forms contain different formats depending on who produced the form,
not all of the information listed in items 1 to 13 may be recorded; however, as much
of this information as possible shall be included.

COC forms tailored to each CTO can be drafted and printed onto multi-ply forms. This eliminates
the need to rewrite the analytical methods column headers each time. It also eliminates the need to
write the project manager, name, and number; QC Level; TAT; and the same general comments each
time.

Complete one COC form per cooler. Whenever possible, place all volatile organic analyte vials into
one cooler in order to reduce the number of trip blanks. Complete all sections and be sure to sign and
date the COC form. One copy of the COC form must remain with the field personnel.

6.	Records

The COC/analytical request form shall be faxed or e-mailed to the CTO Laboratory Coordinator for
verification of accuracy. Following the completion of sampling activities, the sample logbook and
COC forms will be transmitted to the CTO Manager for storage in project files. The data validators
shall receive a copy also. The original COC/analytical request form shall be submitted by the
laboratory along with the data delivered. Any changes to the analytical requests that are required
shall be made in writing to the laboratory. A copy of this written change shall be sent to the data
validators and placed in the project files. The reason for the change shall be included in the project
files so that recurring problems can be easily identified.

7.	Health and Safety

Not applicable.

8.	References

California Environmental Protection Agency (Cal/EPA). 1988. Technical Guidance Manual, Solid
Waste Water Quality Assessment Test (SWAT) Proposals and Reports. Solid Waste Disposal
Program, Hydrogeology Section, Land Disposal Branch, Division of Water Quality, State Water
Resources Control Board. August.

Department of Defense, United States (DoD). 2005a. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-505-
B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the Department
of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line updates
available at: http://www.epa.gov/fedfac/pdf/ufp_qapp_vl_0305.pdf.

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
9 of 26

	. 2005b. Uniform Federal Policy for Quality Assurance Project Plans, Part 2B: Quality

Assurance/quality Control Compendium: Minimum QA/QC Activities. Final Version 1. DoD:
DTIC ADA 426957, EPA-505-B-04-900B. In conjunction with the U. S. Environmental
Protection Agency and the Department of Energy. Washington: Intergovernmental Data Quality
Task Force. March. On-line updates available at: http://www.epa.gov/swerffirr/pdf/-
qaqc_v 1 03 05 .pdf.

	. 2012. Uniform Federal Policy for Quality Assurance Project Plans, Part 2A: Optimized

UFP-QAPP Worksheets. Revision 1. March.

	. 2013. Department of Defense Quality Systems Manual for Environmental Laboratories.

Version 5.0. Draft Final. Prepared by DoD Environmental Data Quality Workgroup and
Department of Energy Consolidated Audit Program Operations Team. July.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

Environmental Protection Agency, United States (EPA). 1978. NEIC Policies and Procedures. EPA-
330/9-78-001-R. Revised August 1991. National Enforcement Investigation Center. Denver.
May.

	. 1988. Guidance for Conducting Remedial Investigations and Feasibility Studies Under

CERCLA. Interim Final. EPA/540/G-89/004. Office of Emergency and Remedial Response.
October.

	. 2007. Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, SW-846. 3rd

ed., Revision 6. Office of Solid Waste. November. On-line updates at:
http://www.epa.gov/epawaste/hazard/testmethods/sw846/online/index.htm.

Procedure I-A-8, Sample Naming.

Procedure III-D, Logbooks.

9. Attachments

Attachment III-E-1, Chain-of-Custody Seal

Attachment III-E-2, Generic Chain-of-Custody/Analytical Request Form

Attachment III-E-3, Sample Completed Chain-of-Custody

Attachment III-E-4, Sample Out-of-Control Form

-------
This page intentionally left blank

-------
Attachment lll-E-1
Chain-of-Custody Seal

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
13 of 26

CHAIN-OF-CUSTODY SEAL

CUSTODY SEAL

Company Name (808) XXX-XXXX

Sampler's Name/Initials:

Date:

Time:

-------
This page intentionally left blank

-------
Attachment lll-E-2
Generic Chain-of-Custody/Analytical Request Form

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
17 of 26

*

I 1

i

5

1
.*

1
«•

I

l

o



(0 1 IHQJL



















i
!
1



OlOH





















asw.'sw













































































































I 010£ VrfJ ** PW1





















P 0i<2B VJ3



























Chain-of-Custody

;

£ \
a

I i

s 5
¦*



ij OWTB Vd3





















| [*fJ« *B3dl DQQS VJ3





















j 410









































i

1

—•

¦ ¦ !
t > *

* > >

> |

i"l ij

i j » * ^ f

d

! 1



j; >VOA9 «





















•*OA rfW





















tsiOdH^L



















*

I

m

£ °
| a

S -H

k A
¦

X

ias*i/*w> pry

















i

i-i

('n* j«&p#vp rwvip) mpo

















li

I:
II



MM

















i«*

















ills

i

m

i

|i

a

s

]
1

4

1

1

J C

? 1 i
I £ j

s s

; i i



?

If

&
t



















£

P

I

I

I

I

i I





















I

I

I

I

•

5

u.

i

i]



















*
s

I

i

™ !

£

*
I
I

i

u
¦S

' —t

I

:

-

4
V

a

a
5

l*

1

DC

i

i

o

1

w

1

s

i

i
i

i

fi
]

_

















£

«

i'



















Generic Chain-of-Custody/Analytical Request Form

-------
This page intentionally left blank

-------
Attachment lll-E-3
Sample Completed Chain-of-Custody

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
21 of 26















A •mvmuoo jo # Fiox

Eg











*

X3
O

>4-»













••pw»*d «no

X

X

X

X

X



X



o























CX



•voas «no

X

X

X

X

X



X



















(A

6

S







**

2

•voa *no

X

X

X

X

X

X

X



















O

9
CJ

u
?

i

£

9
m



"

i



S3103 Hd±

X

X

X

X

X



X



o





X

s

X
0

5





O
c

2
<
u;

O

Sb

a

S



1
*

i

i



Iasw/3W) imotptoQ m











X





w

<

te





>•

is

{.

* "S
« ¥

J



*«5
x:
O









<£.
m.

i

o
a

('«*• *«6pnp 'umf) j»mo

















3





r>

* i

i •

J

fi

it

1 8

i 8
11

u





r

i

-5

T3
<



e

J

£

5

z

•»l»M











X

X







i
J

u

a 5

!•

11

li
! f

ll



©

s

t
s



55



i—

} B°S

X

X

X

X

X











f e
li

i j















1

f



0

1



















«

£
1=

«

£
P

•

£
P

•

E
P

«

£
P

J*

a

i


o
m
&

m
O

in
cs
o

in
*4-
O

in

ID
O

o

ID

Cv





•

a

m

S

2

•

i

0

1

.£

UL

1

1





¦



i

i



i—

2

•

'I

CD

or

i
5)

a>
O)
a

3>

CD



CD

91
«

35

(D

cn
«
a

«

S?
c
ai















>
a.

o
U

«o
<•



£

1

«

J

•

1
I

o
o
o

h*

o

S

i

z
o

D
O
h
O

O

11>
CM

o
o
u

5-

3

z

2

O
H
O

s

1

I

1

1

g



a

1

§
o
<
a.

1
•

U)

i

. . . :
.3

o
d



i

® i5

t£

- g
<_

«c

s

. 3

r».

s

~ 
-------
This page intentionally left blank

-------
Attachment lll-E-4
Sample Out-of-Control Form

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
25 of 26

Status

Date

Initial

Noted 00C





Submit for CA*





Resubmit for CA*





Completed





Date Recognized:

By:



Samples Affected

Dated Occurred:

Matrix



(List by Accession

Parameter (Test Code):

Method:



AND Sample No.)

Analyst:

Supervisor:





1. Type of Event

2. Corrective Action (CA)*







(Check all that apply)



(Check all that apply)







Calibration Corr. Coefficient <0.995



Repeat calibration







%RSD>20%



Made new standards







Blank >MDL



Reran analysis







Does not meet criteria:



Sample(s) redigested and rerun







Spike



Sample(s) reextracted and rerun







Duplicate



Recalculated







LCS



Cleaned system







Calibration Verification



Ran standard additions







Standard Additions



Notified







MS/MSD



Other (please explain)





BS/BSD









Surrogate Recovery





Calculations Error



-------
NAVFAC Pacific ER Program
Record Keeping, Sample Labeling,
and Chain-of-Custody Procedures

Procedure Number:
Revision Date:
Page:

lll-E
May 2015
26 of 26



Holding Times Missed





Other (Please explain

Comments:





























Analyst:

Date:

Supervisor:

Date:

QA Department:

Date:

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
1 of 41

Sample Handling, Storage, and Shipping

1.	Purpose

This standard operating procedure sets forth the methods for use by the United States (U.S.) Navy
Environmental Restoration (ER) Program, Naval Facilities Engineering Command (NAVFAC),
Pacific personnel engaged in handling, storing, and transporting samples.

2.	Scope

This procedure applies to all Navy ER projects performed in the NAVFAC Pacific Area of
Responsibility.

This procedure shall serve as management-approved professional guidance for the ER Program and
is consistent with protocol in the most recent version of the Uniform Federal Policy-Quality
Assurance Project Plan (UFP QAPP) Part 1 (DoD 2005a), 2A (DoD 2012), and 2B (2005b), as well
as the DoD Quality Systems Manual (DoD 2013). As professional guidance for specific activities,
this procedure is not intended to obviate the need for professional judgment during unforeseen
circumstances. Deviations from this procedure while planning or executing planned activities must
be approved and documented by the following prime contractor representatives: the CTO Manager
and the Quality Assurance (QA) Manager or Technical Director. A Navy project representative
(i.e., Remedial Project Manager or QA Manager) shall also concur with any deviations.

3.	Definitions

None.

4.	Responsibilities

The prime contractor CTO Manager and the Laboratory Project Manager are responsible for
identifying instances of non-compliance with this procedure and ensuring that future sample
transport activities are in compliance with this procedure.

The Field Manager is responsible for ensuring that all samples are shipped according to this
procedure.

Field personnel are responsible for the implementation of this procedure.

The QA Manager or Technical Director is responsible for ensuring that sample handling, storage,
and transport activities conducted during all CTOs are in compliance with this procedure.

All field personnel are responsible for complying with Chief of Naval Operations Instruction 5090.1,
under Specific Training Requirements (DON 2014).

5.	Procedures

5.1 Handling and Storage

Immediately following collection, label all samples according to Procedure III-E, Record Keeping,
Sample Labeling, and Chain-of-Custody. In addition, when more than one volatile organic analyte

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
2 of 41

(VOA) vial is used to collect one sample, the chain-of-custody (COC) identification (ID) will be
written on the VOA vials (even pre-tared vials) with a ball point pen for that sample. The lids of the
containers shall not be sealed with duct tape, but should be covered with custody seals (except
pre-tared containers which should have the custody seal placed on the outside of the protective
bubble wrap). Wrap glass sample containers on the sides, tops, and bottoms with bubble wrap or
other appropriate padding to prevent breakage during transport. When collecting three VOA vials per
sample, it is acceptable to wrap all three vials together and store in one plastic bag. Store all glass
containers for water samples in an upright position, never stacked or placed on their sides. Samples
will be maintained as close to 4 degrees Celsius (°C) as possible from the time of collection through
transport to the analytical laboratory, using refrigerators and/or freezers when appropriate. Place all
containers into self-sealing bags and into an insulated cooler with wet ice while still in the field.
Samples should occupy the lower portion of the cooler, while the ice should occupy the upper
portion. Place an absorbent material (e.g., proper absorbent cloth material) on the bottom of the
cooler to contain liquids in case of spillage. Ship samples as soon after collection as possible to allow
the laboratory to meet holding times for analyses. Check with the laboratory for operating/sample
receipt hours prior to all traditional and non-traditional holidays to ensure sample shipment will be
received. When not shipping samples directly upon field collection, store samples in a refrigerator or
freezer (never freeze water samples) until shipped to the laboratory.

5.2	Packing

Each cooler must contain a temperature blank (small plastic bottle with sterile water) to confirm
cooler temperature upon receipt at the laboratory. Water samples can be used as such, but it is best to
include a designated temperature blank bottle, typically supplied by the laboratory with the coolers.

One trip blank must be included in each cooler containing samples for volatile analysis (e.g., volatile
organic compounds, total petroleum hydrocarbons-gasoline range organics.

Cooler must be lined completely in ice at the bottom and all four sides. After confirming all project
samples are accounted for and labeled correctly, place samples in cooler. Record sample IDs on
cooler-specific COC(s). Pack glass containers for water samples in an upright position, never stacked
or placed on their sides. Fill all empty space between sample containers with bubble wrap or other
appropriate material (not Styrofoam). Place a layer of ice on top of samples and fill all empty space
between ice and cooler lid with bubble wrap or other appropriate material.

Place laboratory copies of completed COC(s), and soil permit if applicable, into resealable bag and
tape to underside of cooler lid.

5.3	Shipping

Follow all appropriate U.S. Department of Transportation regulations (e.g., 49 Code of Federal
Regulations [CFR], Parts 171-179) for shipment of air, soil, water, and other samples. Elements of
these procedures are summarized below.

5.3.1 Hazardous Materials Shipment

Field personnel must state whether any sample is suspected to be a hazardous material. A sample
should be assumed to be hazardous unless enough evidence exists to indicate it is non-hazardous. If
not suspected to be hazardous, shipments may be made as described in the Section 5.3.3 for
non-hazardous materials. If hazardous, follow the procedures summarized below.

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
3 of 41

Any substance or material that is capable of posing an unreasonable risk to life, health, or property
when transported is classified as hazardous. Perform hazardous materials identification by checking
the list of dangerous goods for that particular mode of transportation. If not on that list, materials can
be classified by checking the Hazardous Materials Table (49 CFR 172.102 including Appendix A) or
by determining if the material meets the definition of any hazard class or division (49 CFR Part 173),
as listed in Attachment III-F-2.

All persons shipping hazardous materials must be properly trained in the appropriate regulations, as
required by HM-126F, Training for Safe Transportation of Hazardous Materials (49 CFR HM-126F
Subpart H). The training covers loading, unloading, handling, storing, and transporting of hazardous
materials, as well as emergency preparedness in the case of accidents. Carriers, such as commercial
couriers, must also be trained. Modes of shipment include air, highway, rail, and water.

When shipping hazardous materials, including bulk chemicals or samples suspected of being
hazardous, the proper shipping papers (49 CFR 172 Subpart C), package marking (49 CFR 172
Subpart D), labeling (49 CFR 172 Subpart E), placarding (49 CFR 172 Subpart F, generally for
carriers), and packaging must be used. Attachment III-F-1 shows an example of proper package
markings. Refer to a copy of 49 CFR each time hazardous materials/potentially hazardous samples
are shipped.

According to Section 2.7 of the International Air Transport Association Dangerous Goods
Regulations publication, very small quantities of certain dangerous goods may be transported
without certain marking and documentation requirements as described in 49 CFR Part 172. However,
other labeling and packing requirements must still be followed. Attachment III-F-2 shows the
volume or weight for different classes of substances. A "Dangerous Goods in Excepted Quantities"
label must be completed and attached to the associated shipping cooler (Attachment III-F-3). Certain
dangerous goods are not allowed on certain airlines in any quantity.

As stated in item 4 of Attachment III-F-4, the Hazardous Materials Regulations do not apply to
hydrochloric acid (HC1), nitric acid (HN03), sulfuric acid (H2S04), and sodium hydroxide (NaOH)
added to water samples if their pH or percentage by weight criteria are met. Hazardous Materials
Regulations also do not apply to methanol (MeOH) for soil samples if the percentage by weight
criterion is met. These samples may be shipped as non-hazardous materials as discussed below.

5.3.2 Non-hazardous Materials Shipment

If the samples are suspected to be non-hazardous based on previous site sample results, field
screening results, or visual observations, if applicable, then samples may be shipped as
non-hazardous.

If preservatives (HC1, HN03 H2S04 NaOH, or MeOH) are used, ensure their individual pH or
percentage by weight criteria, as shown in item 4 of Attachment III-F-4, are met to continue shipping
as non-hazardous samples.

When a cooler is ready for shipment to the laboratory, place the receiving laboratory address on the
top of the cooler, place chain-of-custody seals on the coolers as discussed in Procedure III-E, Record
Keeping, Sample Labeling, and Chain-of-Custody, place soil permit labels on top if applicable, and
seal the cooler with waterproof tape.

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
4 of 41

5.3.3 Shipments from Outside the Continental United States

Shipment of sample coolers to the continental U.S. from locations outside the continental U.S. is
controlled by the U.S. Department of Agriculture (USDA) and is subject to their inspection and
regulation. A "USDA Soil Import Permit" is required to prove that the receiving analytical
laboratory is certified by the USDA to receive and properly dispose of soil. In addition, all sample
coolers must be inspected by a USDA representative, affixed with a label indicating that the coolers
contain environmental samples, and accompanied by shipping forms stamped by the USDA
inspector prior to shipment. In addition, the U.S. Customs Service must clear samples shipped from
U.S. territorial possessions or foreign countries upon entry into the U.S. As long as the commercial
invoice is properly completed (see below), shipments typically pass through U.S. Customs Service
without the need to open coolers for inspection.

In Hawaii, soil sample shipments are typically brought to the courier at the airport where the courier
contacts a USDA representative to make an inspection. Alternatively, the contractor may enter into
an agreement with the USDA to ship soil samples. In this way, the USDA does not need to inspect
each soil sample shipment. If the contractor maintains a Domestic Soil Permit, place the permit label
and the soil origination label (Attachment III-F-9) on the top of the cooler. Place a copy of the
receiving laboratory's soil permit with the COC inside the cooler. Confirm custody seals were placed
on each container (Section 5.1) to ensure proper chain-of-custody control in the event coolers are
opened for inspection.

In Guam, shipments can be dropped off directly to the Federal Express branch or to the courier at the
airport. Alternatively, the courier can pick up shipments at each site provided that arrangements have
been made regarding pickup time and location. USDA inspections occur outside of Guam. The
laboratory's soil permit shall be placed with the COC inside the cooler, and the soil origination label
(see Attachment III-F-9) should be placed on top of the cooler.

The USDA does not need to inspect water sample shipments.

Completion and use of proper paperwork will, in most cases, minimize or eliminate the need for the
USDA and U.S. Customs Service to inspect the contents. Attachment III-F-5 shows an example of
how paperwork may be placed on the outside of coolers for non-hazardous materials. For hazardous
materials, refer to Section 5.3.1.

In summary, tape the paperwork listed below to the outside of the coolers to assist sample shipments.
If a shipment is made up of multiple pieces (e.g., more than one cooler), the paperwork need only be
attached to one cooler, provided that the courier agrees. All other coolers in the shipment need only
be taped and have address and COC seals affixed.

1.	Courier Shipping Form & Commercial Invoice. See Attachment III-F-6, and Attachment
III-F-7 for examples of the information to be included on the commercial invoice for soil and
water. Place the courier shipping form and commercial invoice inside a clear, plastic,
adhesive-backed pouch that adheres to the package (typically supplied by the courier) and
place it on the cooler lid as shown in Attachment III-F-5.

2.	Soil Import Permit (soil only). See Attachment III-F-8 and Attachment III-F-9 for

examples of the soil import permit and soil samples restricted entry labels. The laboratory
shall supply these documents prior to mobilization. The USDA in Hawaii often does stop

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
5 of 41

shipments of soil without these documents. Staple together the 2 inch x 2 inch USD A label
(described below), and soil import permit, and place them inside a clear plastic pouch. The
courier typically supplies the clear, plastic, adhesive-backed pouches that adhere to the
package.

Placing one restricted entry label as shown in Attachment III-F-5 (covered with clear
packing tape) and one stapled to the actual permit is suggested.

The USDA does not control water samples, so the requirements for soil listed above do not
apply.

3.	Chain-of-Custody Seals. The laboratory should supply the seals. CTO personnel must sign
and date these. At least two seals should be placed in such a manner that they stick to both
the cooler lid and body. Placing the seals over the tape (as shown in Attachment III-F-5),
then covering it with clear packing tape is suggested. This prevents the seal from coming
loose and enables detection of tampering.

4.	Address Label. Affix a label stating the destination (laboratory address) of each cooler.

5.	Special Requirements for Hazardous Materials. See Section 5.3.1.

Upon receipt of sample coolers at the laboratory, the sample custodian shall inspect the sample
containers as discussed in Procedure III-E, Record Keeping, Sample Labeling, and Chain-of-
Custody. The samples shall then be either immediately extracted and/or analyzed, or stored in a
refrigerated storage area until they are removed for extraction and/or analysis. Whenever the samples
are not being extracted or analyzed, they shall be returned to refrigerated storage.

6.	Records

Maintain records as required by implementing these procedures.

7.	Health and Safety

Personnel shall perform work in accordance with the current (or as contractually obligated) United
States Army Corps of Engineers Safety and Health Requirements Manual EM-385-1-1
(USACE 2012) and site-specific health and safety plan.

8.	References

Department of Defense, United States (DoD). 2005a. Uniform Federal Policy for Quality Assurance
Project Plans, Part 1: UFP-QAPP Manual. Final Version 1. DoD: DTIC ADA 427785, EPA-
505-B-04-900A. In conjunction with the U. S. Environmental Protection Agency and the
Department of Energy. Washington: Intergovernmental Data Quality Task Force. March. On-line
updates available at: http://www.epa.gov/fedfac/pdf/uip_qapp_vl_0305.pdf.

	. 2005b. Uniform Federal Policy for Quality Assurance Project Plans, Part 2B: Quality

Assurance/quality Control Compendium: Minimum QA/QC Activities. Final Version 1. DoD:
DTIC ADA 426957, EPA-505-B-04-900B. In conjunction with the U. S. Environmental
Protection Agency and the Department of Energy. Washington: Intergovernmental Data Quality
Task Force. March. On-line updates available at: http://www.epa.gov/swerffirr/pdf/-
qaqc_v 1 03 05 .pdf.

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
6 of 41

	. 2012. Uniform Federal Policy for Quality Assurance Project Plans, Part 2A: Optimized

UFP-QAPP Worksheets. Revision 1. March.

	. 2013. Department of Defense Quality Systems Manual for Environmental Laboratories.

Version 5.0. Draft Final. Prepared by DoD Environmental Data Quality Workgroup and
Department of Energy Consolidated Audit Program Operations Team. July.

Department of the Navy (DON). 2014. Environmental Readiness Program Manual. OPNAV
Instruction 5090. ID. 10 January.

United States Army Corps of Engineers (USACE). 2008. Consolidated Safety and Health
Requirements Manual. EM-385-1-1. Includes Changes 1-7. 13 July 2012.

Procedure III-E, Record Keeping, Sample Labeling, and Chain-of-Custody.

9. Attachments

Attachment III-F-1: Example Hazardous Materials Package Marking
Attachment III-F-2: Packing Groups

Attachment III-F-3: Label for Dangerous Goods in Excepted Quantities
Attachment III-F-4: SW-846 Preservative Exception

Attachment III-F-5: Non-Hazardous Material Cooler Marking Figure for Shipment From Outside
The Continental United States

Attachment III-F-6: Commercial Invoice - Soil

Attachment III-F-7: Commercial Invoice - Water

Attachment III-F-8: Soil Import Permit

Attachment III-F-9: Soil Samples Restricted Entry Labels

-------
Attachment lll-F-1
Example Hazardous Material Package Marking

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
9 of 41

Shipper (1
xv Consignee

dn 30is siHr

THIS SIDE UP

HAZARD
, LABEL >

PROPER SHIPPING NAME

CLASS

UN NUMBER

PACKAGING INSTRUCTIONS,

PACKING GROUP
NET QUANTITY
E.R.G. GUIDE NUMBER

HG/Y40/5/93 (for example)
USA/D.G.C.-M4554 (for

(7") AIR BILL/COMMERCIAL INVOICE (T) DIRECTION ARROWS STICKER -

X US DA PERMIT (Letterto	^ ™° REQUIRED

^1/ Laboratory from USDA)	(7) THIS SIDE UP STICKERS

(7) CUSTODY SEAL	(7) HAZARD LABEL

(7) USDA 2" X 2" SOIL IMPORT PERMIT(7) HAZARDOUS MATERIAL INFORMATION
(7) WATERPROOF STRAPPING TAPE (10) PACKAGE SPECIFICATIONS

-------
This page intentionally left blank

-------
Attachment lll-F-2
Packing Groups

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
13 of 41

PACKING GROUP OF THE SUBSTANCE

PACKING GROUP 1

PACKING GROUP II

PACKING GROUP III

CLASS or DIVISION of PRIMARY or
SUBSIDIARY RISK

Packagings

Packagings

Packagings

1: Explosives

Inner

Outer

Inner

Outer

Inner

Outer

Forbidden (NoteA)



2.1: Flammable Gas

	Forbidden (Note B)	



2.2: Non-Flammable, non-toxic gas



See Notes







2.3: Toxic gas

Fnrhirlrlpn (Note A)	



3. Flammable liquid

30 mL

300 mL

30 mL

500 mL

30 mL

1 L

4.1 Self-reactive substances

Forbidden

Forbidden

Forbidden

4.1: Other flammable solids

Forbidden

30 g

500 g

30 g

1 kg

4.2: Pyrophoric substances

Forbidden

Not Applicable

Not Applicable

4.2 Spontaneously combustible substances

Not Applicable

30 g

500 g

30 g

1 kg

4.3: Water reactive substances

Forbidden

30 g or
30 mL

500 g or
500 mL

30 g or
30 mL

1 kg or
1 L

5.1: Oxidizers

Forbidden

30 g or
30 mL

500 g or
500 mL

30 g or
30 mL

1 kg or
1 L

5.2: Organic peroxides (Notel-,

See Note A

30 g or
30 mL

500 g or
250 mL

Not Applicable

6.1: Poisons - Inhalation toxicity

Forbidden

1 g or 1
mL

500 g or
500 mL

30 g or
30 mL

1 kg or
1 L

6.1: Poisons - oral toxicity

1 g or 1
mL

300 g or
300 mL

1 g or 1
mL

500 g or
500 mL

30 g or
30 mL

1 kg or
1 L

6.1: Poisons - dermal toxicity

1 g or 1
mL

300 g or
300 mL

1 g or 1
mL

500 g or
500 mL

30 g or
30 mL

1 kg or
1 L

6.2: Infectious substances

	Forbidden Ai	



7: Radioactive material(Note u)

	Forbidden (NoteA>	



8: Corrosive materials

Forbidden

30 g or
30 mL

500 g or
500 mL

30 g or
30 mL

1 kg or
1 L

9: Magnetized materials

Fnrhirlrlpn (Note A)	



9: Other miscellaneous materials (Note 1=1

Forbidden

30 g or
30 mL

500 g or
500 mL

30 g or
30 mL

1 kg or
1 L

Note A: Packing groups are not used for this class or division.

Note B: For inner packagings, the quantity contained in receptacle with a water capacity of 30 mL. For outer packagings, the

sum of the water capacities of all the inner packagings contained must not exceed 1 L.

Note C: Applies only to Organic Peroxides when contained in a chemical kit, first aid kit or polyester resin kit.

Note D: See 6.1.4.1, 6.1.4.2 and 6.2.1.1 through 6.2.1.7, radioactive material in excepted packages.

Note E: For substances in Class 9 for which no packing group is indicated in the List of Dangerous Goods, Packing Group II
quantities must be used.

-------
This page intentionally left blank

-------
Attachment lll-F-3
Label for Dangerous Goods in Excepted Quantities

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
17 of 41

DANGEROUS GOODS IN EXCEPTED QUANTITIES

This package contains dangerous goods in excepted small quantities
and is in all respects in compliance with the applicable international
and national government regulations and the IATA Dangerous Goods
Regulations.

Name and address of Shipper

This package contains substance(s) in Class(es)
(check applicable box(es))

Signature of Shipper

Title

Date

Class:

2

3

4

5

6

8

9

and the applicable UN Numbers are:

o

o

o

o

o

o

o

-------
This page intentionally left blank

-------
Attachment lll-F-4
SW-846 Preservative Exception

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
21 of 41

Measurement

Vol. Reg.
imLl

Container2

Preservative J 4 Holding Timeb

MBAS

250
50

P,G
P,G

Cool, 4°C
Cool, 4°C

48 Hours

NTA

24 Hours

1.	More specific instructions for preservation and sampling are found with each procedure as
detailed in this manual. A general discussion on sampling water and industrial wastewater may
be found in ASTM, Part 31, p. 72-82 (1976) Method D-3370.

2.	Plastic (P) or Glass (G). For metals, polyethylene with a polypropylene cap (no liner) is preferred.

3.	Sample preservation should be performed immediately upon sample collection. For composite
samples each aliquot should be preserved at the time of collection. When use of an automated
sampler makes it impossible to preserve each aliquot, then samples may be preserved by
maintaining at 4°C until compositing and sample splitting is completed.

4. When any sample is to be shipped by common carrier or sent through the United States Mail, it
must comply with the Department of Transportation Hazardous Materials Regulations (49 CFR
Part 172). The person offering such material for transportation is responsible for ensuring such
compliance, for the preservation requirements of Table 1, the Office of Hazardous Materials,
Materials Transportation Bureau, Department of Transportation has determined that the
Hazardous Materials regulations do not apply to the following materials: Hydrochloric acid (HCI)
in water solutions at concentration of 0.04% by weight or less (pH about 1.96 or greater); Nitric
acid (HN03) in water solutions at concentrations of 0.15% by weight or less (pH about 1.62 or
greater); Sulfuric acid (H2S04) in water solutions at concentrations of 0.35% by weight or less (pH
about 1.15 or greater); Sodium hydroxide (NaOH) in water solutions at concentrations of 0.080%
by weight or less (pH about 12.30 or less).

5. Samples should be analyzed as soon as possible after collection. The times listed are the
maximum times that samples may be held before analysis and still considered valid. Samples
may be held for longer periods only if the permittee, or monitoring laboratory, has data on file to
show that the specific types of sample under study are stable for the longer time, and has
received a variance from the Regional Administrator. Some samples may not be stable for the
maximum time period given in the table. A permittee, or monitoring laboratory, is obligated to hold
the sample for a shorter time if knowledge exists to show this is necessary to maintain sample
stability.

6. Should only be used in the presence of residual chlorine.

-------
This page intentionally left blank

-------
Attachment lll-F-5

Non-Hazardous Material Cooler Marking Figure for Shipment from

outside the Continental United States

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
25 of 41

(?) AIR BILL/COMMERCIAL INVOICE

@ USDA PERMIT (Letter to Laboratory from USDA)

@ CUSTODY SEAL

(T) USDA 2" X 2" SOIL IMPORT PERMIT

@ WATERPROOF STRAPPING TAPE

@ DIRECTION ARROWS STICKER - TWO REQUIRED

-------
This page intentionally left blank

-------
Attachment lll-F-6
Commercial Invoice - Soil

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
29 of 41

DATE OF EXPORTATION

1/1/94

EXPORT REFERENCES (i.e., order no., invoice no., etc.)



SHIPPER/EXPORTER (complete name and address)

Joe Smith
Ogden

c/o 



CONSIGNEE

Sample Receipt



COUNTRY OF EXPORT

Guam, USA

IMPORTER - IF OTHER THAN CONSIGNEE

COUNTRY OF ORIGIN OF GOODS

Guam, USA

COUNTRY OF ULTIMATE DESTINATION

USA







INTERNATIONAL
AIR WAYBILL NO.



(NOTE: All shipments must be
accompanied by a Federal Express
International Air Waybill)







MARKS/NOS

NO. OF
PKGS

TYPE OF
PACKAGING

FULL DESCRIPTION OF GOODS

QT
Y

UNIT OF
MEASURE

WEIGHT

UNIT
VALUE

TOTAL
VALUE



3

coolers

Soil samples for labors
analysis only







$1.00

$3.00



TOTAL
NO. OF
PKGS.



TOTAL
WEIGHT



TOTAL

INVOICE

VALUE

3



$3.00











Check one

~	F.O.B.

~	C&F

~	C.I.F.

THESE COMMODITIES ARE LICENSED FOR THE ULTIMATE DESTINATION SHOWN.

DIVERSION CONTRARY TO UNITED STATES LAW IS PROHIBITED.

I DECLARE ALL THE INFORMATION CONTAINED IN THIS INVOICE TO BE TRUE AND CORRECT

signature OF SHIPPER/EXPORTER (Type name and title and sign)

Joe Smith, Ogden	Joe Smith	1/1/94

Name/Title

Signature

Date

-------
This page intentionally left blank

-------
Attachment lll-F-7
Commercial Invoice - Water

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
33 of 41

DATE OF EXPORTATION

1/1/94

EXPORT REFERENCES (i.e., order no., invoice no., etc.)



SHIPPER/EXPORTER (complete name and address)

Joe Smith
Ogden

c/o 



CONSIGNEE

Sample Rece




COUNTRY OF EXPORT

Guam, USA

IMPORTER - IF OTHER THAN CONSIGNEE

COUNTRY OF ORIGIN OF GOODS

Guam, USA

COUNTRY OF ULTIMATE DESTINATION

USA







INTERNATIONAL
AIR WAYBILL NO.



(NOTE: All shipments must be
accompanied by a Federal Express
International Air Waybill)







MARKS/NOS

NO. OF
PKGS

TYPE OF
PACKAGING

FULL DESCRIPTION OF GOODS

QT
Y

UNIT OF
MEASURE

WEIGHT

UNIT
VALUE

TOTAL
VALUE



3

coolers

Water samples for labc
analysis only







$1.00

$3.00



TOTAL
NO. OF
PKGS.



TOTAL
WEIGHT



TOTAL
INVOICE
VALUE

3



$3.00











Check one

~	F.O.B.

~	C&F

~	C.I.F.

THESE COMMODITIES ARE LICENSED FOR THE ULTIMATE DESTINATION SHOWN.

DIVERSION CONTRARY TO UNITED STATES LAW IS PROHIBITED.

I DECLARE ALL THE INFORMATION CONTAINED IN THIS INVOICE TO BE TRUE AND CORRECT
signature OF SHIPPER/EXPORTER (Type name and title and sign)

Joe Smith, Ogden	Joe Smith	1/1/94

Name/Title

Signature

Date

-------
This page intentionally left blank

-------
Attachment lll-F-8
Soil Import Permit

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program	Procedure Number:

Sample Handling, Storage, and Shipping	Revision:

Page:

lll-F
May 2015
37 of 41

'jjkr

-U

O

o

CD

^ I

i-S
11

cr Z

CD" O

cr

it

3 M.
o *

a a

3 5'

if

s  s

CD = CD
CL r- 03

a 3 5.

8 §
lis.

"5 § 3

i if

1 a 3

rj crs (D
8 §> 5-

B 8 s

5J =

CD £. "

8 S"

a>3

C 0)
£2. =3
O CL

^ (5
a 3

IT c

a> 2.
w

pi CO
CD

II

5 w
cd _
o P

O o
— CL

o* 5

a S

9 CO

5, O
~
to

§

(J 03

e w

| I

§ to
 5"
r:- 03 03

3" ^

5 "O

(0 CD 03 -i

a 30 '
¦o 

¦SMS
S3 a?

o 3 X 8>

O S X =•

= sr Dx

03 3

- 55

0) -
3 CD
CL 3

(ft

CD

c

iEr
o
3.
N
03

i" cd
Pom

< g i 5T

o ? <£ °

5 3 3 o

L » Jj
ft 5T » g.

3 3 cr -r

_ o cr rti m

^|!ȤS
•§-83

c *< 3 0>

5 " -§ iff

O 3" C
O (0 3

IP

§5 3
« s ®

5 fi)

11

o S-

Jo ~

<0 2,—

on
(ft
C
o
a.

* 71
(0 w

m
x
x
o
z

5 o
CD

IS

O (D	K.
O- °* c=

~ P	s

3	n>

= ®

» n

"5. ®

3 & »*

Q. ®

< a. w

o

QJ w

¦a S3

X T4

2 3

Fo

s-

U)	^
o

TJ	CD

0	cn
3.	_.

. O	3
-*» 0.

©	c

1	Q.

a tr
~ CD

e «
5 I

X3 2,

0	g

1%

oj a-

3 B

Q. =

T3 CD

1	1
n g

< ffi §

S 5-

-=:	n,

^ 03

Q
c

QJ

3

o_
5

Q.
3

CO

o

03

c
c
CD

^ J"

o ^

CD
TJ
CD

n
g_
c
3
cr
S*
>

C/3 -
Q C/3 O.T3

> 2. « o

it ffi m -*

8 | P-®
3 g

3 a 3 o

l-s

>< 9 tu

t 3 "**!

Sis

< > O
CD CD q
•< CD -O

C § CD
-< 3 3
T3 CD O

C
oa_

3
0)

3

CD ~
CL>

fl) n
cr ~
o o
<

CD ^

(A Oj

S N>
O ^

X. ^
©

-H ^

o; ®
o 3
S U)
5* %
to o

O

	 	 cu —

» >1® £
< ^ 2. 03

S >

3" 3

3 >

*9- <

o fl>

3 c

tD fD
CD
CD

Q3_

¦a

a

CO
ID

I
s

Co
©
5S:

IP

Z X

C CD

3 1

rr

-------
This page intentionally left blank

-------
Attachment lll-F-9

Soil Samples Restricted Entry Label and Soil Origin Label

-------
This page intentionally left blank

-------
NAVFAC Pacific ER Program
Sample Handling, Storage, and Shipping

Procedure Number:

Revision:

Page:

lll-F
May 2015
41 of 41

U.S. DEPARTMENT OF AGRICULTURE
ANIMAL AND PLANT HEALTH INSPECTION

PLANT PROTECTION AND QUARANTINE
HYATTSVILLE, MARYLAND 20782

SOIL SAMPLES
RESTRICTED ENTRY

The material contained in this package
is imported under authority of the
Federal Plant Pest Act of May 23, 1957.

For release without treatment if
addressee is currently listed as
approved by Plant Protection and
Quarantine.

(JAN 83)

Soil Samples Restricted Entry Label

SOIL ENCLOSED

SERVICE

PPQ FORM 550

Edition of 12/77 may be used

Origin of Soil

Soil Origin Label

-------
This page intentionally left blank

-------
STATE OF HAWAII
DEPARTMENT OF HEALTH
SOLID AND HAZARDOUS WASTE BRANCH
UNDERGROUND STORAGE TANK SECTION

EMERGENCY ORDER

TO: THE UNITED STATES DEPARTMENT OF THE NAVY,

Docket No. 21-UST-EA-02

c/o REAR ADMIRAL TIMOTHY KOTT,



COMMANDER NAVY REGION HAWAII,

Re: Emergency Change-ln-Service



and Defueling of 20

850 Ticonderoga St., Suite 110

Underground Storage Tanks,

JBPHH, Hawaii 96860-5101,

Red Hill Bulk Fuel Storage



Facility

Respondent.



This Emergency Order ("EO") is an administrative action initiated pursuant to chapters 91 and 342L of the
Hawaii Revised Statutes (HRS) and chapters 11-1 and 11-280.1 of the Hawaii Administrative Rules
(HAR) by the DEPARTMENT OF HEALTH (the "Department") against THE UNITED STATES
DEPARTMENT OF THE NAVY, c/o ADMIRAL TIMOTHY KOTT, COMMANDER NAVY REGION HAWAII
(the "Respondent") and is based upon recent impacts on the Respondent's drinking water system
incident to the operation of the Red Hill Bulk Fuel Storage Facility (the "Facility"). Respondent is the
owner and operator of the Facility. This EO concerns only the issues identified herein and does not
function to preclude or limit actions by any public agency or private party. The Department reserves the
right to bring other actions as may be necessary to protect public health and the environment.

I. AUTHORITY AND BACKGROUND

Section 342L-9, HRS, states that:

"§342L-9 Emergency powers; procedures, (a) Notwithstanding any other law to the
contrary, if the governor or the director determines that an imminent peril to human
health and safety or the environment is or will be caused by:

(1)	A release;

(2)	Any action taken in response to a release from an underground storage tank or
tank system; or

(3)	The installation or operation of an underground storage tank or tank system;
that requires immediate action, the governor or the director, without a public hearing,
may order any person causing or contributing to the peril to immediately reduce or
stop the release or activity, and may take any and all other actions as may be
necessary. The order shall fix a place and time, not later than twenty-four hours
thereafter, for a hearing to be held before the director.

(b) Nothing in this section shall be construed to limit any power which the governor
or any other officer may have to declare an emergency and act on the basis of such
declaration, if such power is conferred by statute or constitutional provision, or
inheres in the office."

Page 1 of 5

-------
Docket No. 21 -UST-EA-02

Situation

On or about November 28, 2021, the Respondent began receiving complaints from
water users from the Respondent's water system regarding a gas or fuel odor from
their drinking water.

On or about December 2, 2021, the Respondent identified the source of fuel
contamination to be the Red Hill Shaft, one of the drinking water sources that
services the Respondent's water system.

As of December 3, 2021, the Department received nearly 500 complaints, mostly
from residents or customers serviced by the Respondent's water system
complaining of fuel or chemical smell from their drinking water.

The are no on-site remedies available to treat the water prior to distribution.

Background

On January 13, 2014, the Respondent discovered a loss of fuel from Tank #5 of its
twenty (20) bulk fuel storage tanks (the "Bulk Fuel Storage Tanks") at the Facility and
immediately notified the Department and the United States Environmental Protection
Agency ("EPA") (collectively the "Regulatory Agencies"). On January 16, 2014, the
Respondent verbally notified the Department and EPA of a confirmed release of a
regulated substance from Tank 5. On January 23, 2014, the Respondent provided
written notification to the Department. The Respondent estimated the fuel loss at
approximately 27,000 gallons.

On 2015, the Respondent, the Defense Logistics Agency and the Regulatory
Agencies entered into an Administrative Order on Consent (the "AOC") to take steps
to ensure that the groundwater resource in the vicinity of the Facility is protected and
to ensure that the Facility is operated and maintained in an environmentally
protective manner.

On March 17, 2020 and June 2, 2020, the Respondent notified Department of a
release of a regulated substance to surface water at Hotel Pier. In a letter dated
June 30, 2021, the Department made the determination that a release occurred from
the Facility.

On May 7, 2021, the Respondent reported a pipeline release of a regulated
substance that occurred on May 6, 2021 that released approximately 1,000 gallons
of fuel, which a significant portion was recovered. Based on the Respondent's report
of Root Cause Analysis of the JP-5 Pipeline Damage, dated September 7, 2021, the
pipeline releases near Tanks #18 and #20 were due to a dynamic transient surge
resulting from the Control Room Operator failure to follow the valve opening and
closing sequence. The Respondent estimated the amount of JP-5 released in the
lower Red Hill Tunnel was 1,618 gallons, of which 1,580 gallons were recovered.
The Respondent reported that 38 gallons were unaccounted for and, therefore,
released into the environment.

On July 23, 2021, the Respondent submitted a confirmed release notification form
that indicated that approximately 150 gallons of a regulated substance was released
at Kilo Pier in a boomed area of the surface water. Approximately 110 gallons were
recovered.

On November 9, 2021, the Department was informed by the media of another surge
event that occurred on September 29, 2021. After an inquiry by the Department, on
November 12, 2021, the Respondent asserted on November 17, 2021 that no
release occurred during the event.

On November 20-21, 2021, the Respondent reported a release of water and fuel
from a crack in a valve in the fire suppression drain line and at the time about 9,000
gallons were recovered. According to the Respondent's press release,

Page 2 of 5

-------
Docket No. 21 -UST-EA-02



approximately 14,000 gallons of water and fuel were contained and recovered. The
incident occurred % mile downhill from the bulk fuel storage tanks. The
Respondent's investigation regarding the release is ongoing.

On November 29, 2021, Admiral Samuel Paparo, Commander, U.S. Pacific Fleet
ordered a command investigation into the November 20, 2021, incident and
reopened the investigation on the May 6 incident.

On December 5, 2021, the Respondent submitted to the Department a Confirmed
Release Notification Form, for the November 20, 2021 release of approximately
14,000 gallons of a mix of water and fuel from a fire suppression drain line in the
tunnel downhill of the Bulk Fuel Storage Tanks.

Additional
justification

The Respondent has consistently been unable to submit AOC deliverables to the
satisfaction of the Department.

The 2021 incidences directly refute the Respondent's claims in the Tank Upgrade
Alternatives Decision Document that the Red Hill "system of systems" is protective of
groundwater. The Respondent's tank upgrade proposal recommends continuing
current design and operation. The Regulatory Agencies disapproved the
Respondent's submission in 2020 and the Respondent's resubmission is significantly
flawed and fails to adequately address key regulatory concerns.

The Respondent's Groundwater Flow Model outputs do not match important field
conditions, and therefore are unreliable for decision-making. Beginning no later than
2018, the Regulatory Agencies have repeatedly and consistently provided, and
Respondent has consistently rejected, significant technical corrective comment on
the Respondent's Conceptual Site Model, the purpose of which is to describe the
hydrogeologic site conditions, and Respondent's preliminary Groundwater Flow
Models, the purpose of which is to determine groundwater movement as may be
related to contaminant transport. The deficiencies in both models have not been
adequately addressed.

The Investigation and Remediation of Releases report is based on the Respondent's
groundwater flow model and therefore cannot be accepted as an appropriate long-
term remedy for all types of future releases. Thus, significant progress to mitigate
the risk of future releases has not been made.

In addition, water quality data show significant increases in total petroleum
hydrocarbon as oil detections at Red Hill Shaft and relative increases around the
Bulk Fuel Storage Tanks. While the May 6 incident is a possible cause of the
increase, the size of the impact area shown in the well data does not appear to
correlate with the Respondent's description of the incident (release of 38 gallons to
the environment—far less than would be expected given the increased
concentrations observed in the well field since the May 6 event). This type of
uncertainty diminishes timely and accurate identification of risk and associated
response measures. This uncertainty, together with delays in receiving laboratory
data, limits the Respondent's ability to activate appropriate spill response actions and
opportunities for rapid response.

The November 20, 2021 incident may have also released a mixture of water and fuel
into the environment. The incident location is significantly closer to the Red Hill
Shaft. This additional uncertainty without in-place recovery and remedial measures
increases risk.

The Facility does not provide necessary environmental protection to rapidly identify
and remediate fuel leaks. The Facility lacks infrastructure and procedures to rapidly
identify and contain subterranean fuel spills and treat drinking water to ensure safe

Page 3 of 5

-------
Docket No. 21 -UST-EA-02

and clean drinking water is continuously available to Respondent's water customers.

Given the number of incidences that have occurred at the Facility within the last year,
and in view of the current drinking water contamination, the Respondent has not
demonstrated that immediate and appropriate response actions are available, and
therefore cannot ensure that immediate and appropriate response actions will be
available should another release occurs in the future. The risk of any additional
contaminants in the aquifer or lack of immediate action now may exacerbate the
current situation and further jeopardize our aquifer system.

II. ORDER

Respondent is hereby ordered to:

1.	Immediately suspend operations including, but not limited to, fuel transfers at the Bulk Fuel
Storage Tanks at the Facility. Respondent shall, however, maintain environmental controls,
release detection and release response protocols, and compliance with applicable regulations.

2.	Take immediate steps to install a drinking water treatment system or systems at Red Hill Shaft to
ensure distribution of drinking water conforms to the standards prescribed by the Safe Drinking
Water Act and applicable regulations and minimize movement of the contaminant plume(s). The
treatment system(s) shall be reviewed and approved by the Department prior to installation and
shall be installed as expeditiously as practicable.

3.	Within 30 days of receipt of this EO, submit a workplan and implementation schedule, prepared
by a qualified independent third party approved by the Department, to assess the Facility
operations and system integrity to safely defuel the Bulk Fuel Storage Tanks. Upon the
Department's approval of the assessment, workplan and implementation schedule, conduct
necessary repairs and make necessary changes in operations to address any deficiencies
identified in the assessment and workplan. Corrective actions shall be performed as
expeditiously as possible.

4.	Within 30 days of completion of required corrective actions under Item 3, defuel the Bulk Fuel
Storage Tanks at the Facility. Any refueling shall be subject to a determination by the
Department that it is protective of human health and the environment.

5.	Within 30 days of receipt of this EO submit a workplan and implementation schedule, prepared by
a qualified independent third party approved by the Department, to assess operations and system
integrity of the Facility to determine design and operational deficiencies that may impact the
environment and develop recommendations for corrective action. Submit the assessment,
proposed work and recommendations for corrective action to the Department with an
implementation schedule. Upon the Department's approval, perform work and implement
corrective actions. Corrective actions shall be performed as expeditiously as possible.

This EO becomes final and enforceable after a hearing which is currently scheduled for December 7,
2021, at 1:00 p.m. with the Department's Hearings Officer via Zoom, or other similar electronic platform
(with links to be provided to both Respondent and the public for their participation). If you wish to waive
your right to contest this EO at a hearing, you may communicate this intention to the Hearings Officer, c/o
Director of Health, Department of Health, 1250 Punchbowl Street, Third Floor, Honolulu, HI 96813 and to
the Solid and Hazardous Waste Branch, Department of Health, 2827 Waimano Home Road #100, Pearl
City, Hawaii 96782. Waiver of the hearing will obligate you to comply with this EO.

At the hearing, you may seek to avoid any obligations prescribed in this EO, and the Department may
seek to impose any additional obligations necessary to protect public health and the environment. Parties
may present evidence and witnesses on their behalf, and may examine and cross-examine all witnesses

Page 4 of 5

-------
Docket No. 21 -UST-EA-02

and evidence presented by the Department. Parties may be represented by attorneys at their own
expense, or they may represent themselves. Any hearing will be in accordance with chapter 91, HRS,
and chapter 11-1, HAR. The final administrative decision will be made at the conclusion of the hearing
and will be based upon all the evidence presented during the hearing.

If you have questions, please call Lene Ichinotsubo, P.E., Acting Chief of the Solid and Hazardous Waste
Branch at (808) 586-4226. If you have special needs due to a disability and require accommodation to
aid you in participating in the hearing or pre-hearing conference, please contact the Hearings Officer at
(808) 586-4409 (voice) or through the Telecommunications Relay Service (711), at least ten (10) working
days before the hearing or pre-hearing conference date.

DATED:	Honolulu, Hawaii	Dec 6, 2021	

DEPARTMENT OF HEALTH
STATE OF HAWAII

KATHLEEN S. HO

Deputy Director for Environmental Health

APPROVED AS TO FORM:

Wade H. Hargrove III
Deputy Attorney General

Page 5 of 5

-------
X	/ AMERICA'S

SfHflW

Press Office > Press Briefings >

CNO, SECNAV, and Deputy
Commander of U.S. Pacific Fleet
Speak During Press Conference in

Hawaii

bv Chief of Naval Operations Public Affairs

07 December 2021

The Secretary of the Navy (SECNAV) Carlos Del Toro, Chief of Naval Operations
(CNO) Adm. Mike Gilday, and Deputy Commander of U.S. Pacific Fleet Rear
Adm. Blake Converse spoke during a press conference in Hawaii on Dec. 6,

2021.

MODERATOR: All right, everybody. Thanks so much for coming today.
Obviously, on the record. We'll start with a brief opening statement from the
secretary of the Navy, Carlos Del Toro, and then Chief of Naval Operations
Admiral Mike Gilday will make a few opening comments.

We're going to try and get around to everybody, so I'll do my best to hit
everybody. We have about 40 minutes, so one question and one follow-up
max, please. And we'll go ahead and start.

So, Mr. Secretary, over to you, sir.

SECRETARY CARLOS DEL TORO: Well, good afternoon, everyone. Thank you
for the opportunity to come here before you today and the people of Hawaii.

I'd like to first start off by apologizing to all of our servicemembers, our DOD
civilians, our contractors, our family members, and the people of Hawaii who
have been affected by this horrible, horrible tragedy. Your health and well-being
is our top priority, both while we are here on the island and while I am back in
Washington, D.C.

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

1/12

-------
For the past two days, the chief of naval operations and I have met and actively

^^^^

ever^ossml^wa^ujncfer^tancmo^Msmptiv^ni^ia^eern^ou^faM^^^

lives, and I am committed to finding and fixing the root cause of this issue.

The CNO and I have visited several areas, to include the Red Hill storage
facility, to learn about possible causes and determine ways to prevent this from
ever happening again. While we are getting closer to determining the root
cause of this situation, there is an ongoing investigation that is led by U.S.
Pacific Fleet into the cause of the incident. Once that investigation is
complete, we will review those findings and adjust our operating procedures as
necessary. This will allow us to implement new safety actions before resuming
operations.

Behind the health of those affected, which is my principal priority, our second
priority is to fix the problem and getting you back to a new normal with regard
to the operation of Red Hill, one where you do not have to worry about this ever
happening again. Each of you should always feel confident that you and your
families are drinking safe and clean water.

I know there are concerns that we have not been transparent with the results of
our testing and our procedures. You have my commitment and promise that
the information that we provide is the most accurate information that we have
available.

Lastly, I want to sincerely thank the governor of Hawaii, the Hawaii
congressional delegation, the Hawaii Department of Health, the Honolulu
Board of Water Supply, and other civilian agencies that we have been working
with to solve this issue. I'm very pleased to say that in the couple of days that
I've been here there's been tremendous collaboration amongst these agencies
and public officials. And I'm deeply to their advice, their counsel, and their
assistance. We simply cannot do it alone, and this will require continued
collaboration with them as well.

Now I'd like to turn it over to the chief of naval operations, Admiral Gilday, for
his opening comments. Thank you.

ADMIRAL MICHAEL M. GILDAY: Mr. Secretary, thank you. And thank you for
joining us this afternoon. It's really important that we have this engagement
and this discussion.

The secretary and I are also joined here in Hawaii by our senior enlisted in the
United States Navy, the master chief petty officer of the Navy, Master Chief
Smith, who's sitting in the room as well. The three of us are in Hawaii for one
single reason, and that is to listen to those that have been affected and to

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

2/12

-------
In the past 24 to 36 hours, we've been exposed to a lot but nothing more

II Search

ocusecRxHnr^^Dnontie^wnicr^ir^iT^rounaecnjporH^stonn^ms^itruiot
only our families but also with the local community, the government, and the
congressional delegation that represents this fine state.

The first priority is to take care of everybody that's been affected by this - by
this situation. And so that includes medical care. That includes food and it
includes water. It also includes alternative housing if that's required.

The second is - as the secretary mentioned, is to restore water service as
quickly as we can. But the key point here is that getting it right is more
important than doing it fast, because what we don't want to do is to move
people back into their homes, to restore service prematurely before we have
the utmost confidence in that system, so that we're not going through this
again.

And so, to that important reason, it's really critical that we do this in
conjunction with and in partnership with both the Department of Health and
the Board of Water Safety, both of whom have been extraordinary in reaching
out to us and collaborating with us and giving us candid feedback on what
we're doing right and what we're not doing right. And we honestly welcome
that. We welcome that kind of - we welcome that kind of help.

The last thing, I'll just emphasize something that the secretary said with
respect to priority three, and that is getting this right for the long term. We
know that this is - this is not a get it done before Christmas of 2021 effort; this
is a long-term effort that we need to get right - and as we just finished up a
call with the congressional delegation for this state, that we need to make it
right forever. And so we are - we are committed to that.

And with that, we're happy to take your questions.

MODERATOR: All right. Audrey from AP, we'll start with you.

Q: OK. Sorry. Could you tell us what the status is right now of the Red Hill fuel
tanks? Are you using them? And, yeah, if you could let us know.

MODERATOR: Do you want to address that, or?

SEC. DEL TORO: Actually, Admiral Converse, why don't you address that?

REAR ADMIRAL BLAKE CONVERSE: So the Red Hill fuel tanks have not been
operationally used since the 27th of November. And so -

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

3/12

-------
MODERATOR: Sure.

operations there.

SEC. DEL TORO: So, actually, it'll have a very minimal effect, if any at all, right
now. I don't want to get into topics or conversations with regards to how long
we can continue to do this for national security reasons, but there's really no
minimum operation to our fleet's activities or activities impacting the Air Force
or the Army or the Marine Corps for any near term at all.

MODERATOR: All right. Star-Advertiser, we'll come to you, Kevin.

Q: OK. I have a follow up on that in terms of readiness. Maybe it has a
minimal impact on that, but it does seem in the long term that the source of
fuel that makes our ships and planes operate is making the troops who use
them sick. That seems to me like a readiness problem. Would you agree with
that?

SEC. DEL TORO: Well, it's not the fuel itself that's making them sick; it's the fuel
in the water that's making them sick. And so the investigation and the
activities that have been going on here now for the good part of a week,
actually, is to determine exactly where the source of contamination is from and
to put a stop to that source of contamination, and then to learn those lessons,
change our operating procedures. And that's all part of the ongoing
investigation that will be conducted.

ADM. GILDAY: I'd just add that there's three things we have to get right. And
this isn't a balance, it's about getting three things right. And so one of them is
safety of people, right? The second is the safety of the environment. And the
third is national security. Those are three things that - you know, as part of
this effort, those are three main things that we're focused on ensuring that we
- that we protect.

MODERATOR: All right. We'll come to HawaiiNewsNow, Mahealani
Richardson.

Q: Mr. Secretary, is there any consideration to permanently shut down the fuel
tanks at Red Hill?

SEC. DEL TORO: We look at all options and all options are on the table,
certainly. But we're looking at some very serious options here in the very near
future, before I depart the island of Oahu. I still need some more time to meet
with additional groups and talk to different folks and look at some additional
facts before I make a determination of what steps I need to take here in the

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

4/12

-------
Q: There's been confusion amongst the families if all of the water at Hickam

SEC. DEL TORO: Admiral, would you care to address the issue of water across
the entire base?

REAR ADM. CONVERSE: So I apologize, first, for any confusion that there may
be. There is - this is a dynamic situation as we've identified the nature of the
constituents, and then we've identified through all of the complaints that we've
had and through extensive sampling both by us and the Department of Health
from Hawaii where the concentration of contaminants are. We've adjusted the
guidance, as has the Department of Health, and we recently - just last night -
put out revised guidance that was conducted in - with consultation from each
of the services' medical centers - the Army - local Army surgeons, the local
Air Force medical community, the local Coast Guard, the Navy, and the
Department of Health toxicologist. And that guidance provides clear
understanding for folks that read that of what your - what your risks are and
what you can do with the water if you're in an area that's affected - and there's
a map online that provides you that indication - and if you're in an area that's
unaffected.

So we just recently put that guidance out. It was developed in consultation
with the entire community that lives here among the medical folks that deal
with that and in consultation with the Department of Health.

MODERATOR: All right. Wyatt Olson, I'll come to you next, from Stripes.

Q: Yeah. Hi. I'd like to burrow down a little bit on where you think this
contamination came from into the well. You said you're looking into that. Like,
how will you do that? How do you figure out where that - how do you trace
that? What are you - what are you doing to trace that?

SEC. DEL TORO: We'll follow the evidence, and that's exactly what we will do.
You know, I believe the evidence will lead us to the root cause of what caused
the contamination into the water supply. And as you know, there were a series
of events that took place in May and earlier in November, and the investigation,
I believe, will - is doing everything it can to basically tie all of those pieces
together to come to a conclusion as to where exactly the water supply was
contaminated.

Would you like to add anything else?

REAR ADM. CONVERSE: I think the testing is - so, to the secretary's point, you
really do have to follow the facts. And science helps us here, right, with
respect to the degree of fidelity you can get from some of this testing to

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

5/12

-------
the Department of Health, with Bureau of Water Supply, who have - actually

MODERATOR: All right. We'll come to Nicole Tarn with KITV.

Q: I have two questions.

The first is both of you gentlemen mentioned that long-term plan is to, of
course, improve the situation and make sure it doesn't happen again. While
that sounds great, logistically how does that look like? What kind of
consideration is part of the plan? Are you adding resources? What is the plan?

SEC. DEL TORO: Yeah. There's a lot of all of the above, actually. We're not just
looking at the long-term plan; we're looking at the steps that need to be taken
today, the steps that need to be taken in the next few days, the next few weeks,
and then of course the longer, more capital investment-intense investments
that need to be made in Red Hill to bring it up to a higher level of proficiency.

You know, I - in my own thoughts, I do believe that we should operate Red Hill
as if it was one of our nuclear-powered submarines or one of our nuclear-
powered aircraft carriers, which is by the way why we have a nuclear powered-
qualified admiral here who's overseeing the operation. But there are
investments that - longer-term investments that also need to be made and
studies that need to be looked at, as well, too.

Chief, would you mind - Admiral, would you mind -

Q: What are the steps?

SEC. DEL TORO: Yeah. Would you mind expanding upon that and the steps
specifically?

ADM. GILDAY: So I think - to expand on what the secretary said, I think first
and foremost taking a look at - taking a look at Red Hill. And so taking a
deeper look at both the material condition of Red Hill as well as taking a look at
the people piece of it, right - the certification and the training of the individuals
that run that facility day in and day out.

We think - we're coming to the conclusion that the investigation that's ongoing
is going to give us some good insights, but perhaps we're also considering
other alternatives with respect - as an example, to take a look at perhaps an
independent study of that as well. And as you all know, there have been many
studies that have been undertaken on Red Hill - fueling system, the water
system - and we are also taking a closer look at them, as well, to inform us on

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

6/12

-------
Q: And then my second question was that there were reports that the Navy

REAR ADM. CONVERSE: I can address that, sir.

So there were indications that there were total hydrocarbons in the
groundwater at monitoring wells in the vicinity of the Red Hill shaft. And we
have a series of monitor wells around the Red Hill complex that allows us early
detection of hydrocarbons, and if we defect those then we make decisions on
what the risk is to the water in the aquifer based on that. We did detect
elevated hydrocarbons for two weeks at one point and then another two weeks
at another point -

Q: In June?

REAR ADM. CONVERSE: - in the June-July-August timeframe. In each of
those cases, as soon as we got those results back from the independent lab,
we notified the Department of Health in Hawaii and we consulted with them,
and we increased monitoring in those monitor wells at their direction. And in
both of those cases, over time that - those hydrocarbon levels decreased back
to non-detectable levels.

Now, recognize these monitor wells are not the same as the well that we're
drawing the water, the Red Hill shaft well.

ADM. GILDAY: Can I just add one thing? I think an important point there is the
admiral used the word "we." He was really talking about the Navy and the
Department of Health, right? And so the Department of Health, in that
oversight role, they need to - they need to take a look at those test results
which we share with them as soon as possible, and then they really have the -
have a determining role on next steps.

Q: I know I'm breaking the rules, but just to follow up, so why was the public
not informed in that period about that elevated hydrocarbon level?

REAR ADM. CONVERSE: Those elevated hydrocarbons were not in the water in
the aquifer that was being pumped; that was in the monitor wells, which are
measuring the groundwater in the vicinity of the Red Hill complex.

Q: So no consumption?

REAR ADM. CONVERSE: Not based on the monitoring that we've conducted at
that time.

Q: Thank you.

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

7/12

-------
SEC. DELTORO: It's fair to say - no, I just want to add one thing. I think —

REAR ADM. CONVERSE: Absolutely.

SEC. DEL TORO: And those were - I assume those were within limits.

REAR ADM. CONVERSE: Sir, there's testing that's done periodically in each of
the wells that we pump our water from, as well, and those tests are done and
are monitored and reviewed by the regulatory authority. And we submit those
samples, as we did these, to the Department of Health.

MODERATOR: All right. We'll come to HPR next.

Q: Just want to get back to the issue of transparency. Everything we've heard
from families, from state officials, Board of Water Supply, there's a lack of
transparency. For instance, they were not notified - Board of Water Supply
was not notified when you shut down drawing from the Red Hill well. So I just
want to ask, why? Why is this lack of transparency going on? Why is the state
Department of Health having to write you a letter over the weekend saying we
need this information, we need these documents we need this - these testing
results because we're not getting what we need? Why is this going on?

SEC. DEL TORO: So I can't speak to the past, certainly, and I don't doubt that
there has been issues associated with perhaps the timing of when information
is transferred across or anything like that. And those issues are of deep
concern to me because we are committed to be as transparent as possible.
There's no question about that. In fact, we're putting all these samples that are
being taken - we've sampled over 500, you know, individual samples. And you
know, as they become available, for example, they're being posted to a website
that the Department of Health can look at, the Hawaii Board of Water Supply
can look at, or any individual citizen can actually go on and look at it.

So, you know, I don't doubt that there are people that feel that we're not being
transparent, and I certainly wish I could address them individually as to why
they felt that they're not being transparent. But what I do know is that for as
long as I've been here there has been absolutely no lack of transparency. We
are communicating as much as we can and informing people as quickly as we
can.

As you can imagine, when the Red Hill shaft was closed the immediate urgency
was to actually get the water supply secured. And you know, I was notified
early the next day that, you know, it had been shut down. And so there's going
to be, I think, a natural lag in terms of timing as to when things do occur,
especially if they're occurring late at night or early in the morning.

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

8/12

-------
But I'm - we're committed - completely committed to transparency. We're not

ADM. GILDAY: We're trying to overcommunicate.

SEC. DELTORO: Yeah. Yeah, we are.

Q: So in terms of rebuilding trust in the Navy, we've heard comments from
Congressman Case, who says the trust in the Navy has been compromised by
this issue. Anything that you say now is likely to be taken with a grain of salt.
How do you rebuild that trust with the public, with your families, with the public
in general that you are accomplishing what you say you are?

SEC. DEL TORO: Yeah. I think we build it one day at a time, one individual at a
time, one situation at a time, by always doing the right thing. That's the only
way that we can do it. To say otherwise would be foolish.

So we are committed to rebuilding this trust. We're doing everything we can to
try to fix the problem and to take care of our people in every possible way. And
the resources of the entire Department of the Navy, and the Department of
Defense for that fact, are being made available to take care of our people, fix
the water supply, and get back on track.

ADM. GILDAY: It needs to be about less say and more do.

SEC. DELTORO: Yeah.

ADM. GILDAY: And quite honestly, we appreciate the spotlight. It makes us
better in that regard with respect to holding us honest to our - to our assertion
that we - that we aspire to be more transparent.

So we need to do more sessions like this. We need to do more sessions like
this together with the local government and those - right, side by side, so that
- so that we can - so that we can basically open the books to everything.

MODERATOR: All right. We'll come to KHON next.

Q: Well, a couple of questions.

Mr. Secretary, you had a meeting with the governor, I believe?

SEC. DELTORO: I did. Yes, sir, today around noontime.

Q: I guess, what could you tell us there? Was there satisfaction on both

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

9/12

-------
SEC. DEL TORO: I don't want to speak for the governor, but I believe so. I think
I Search

jusHiK^RIicmit^ac^iinc^ve^on^^ormer^ocla^^xplainecnn^^^^^
situation as to what was occurring. I explained the steps that we, the
Department of the Navy and the Department of Defense, are taking to take care
of our people, to try to fix the problem, and to get us to a better place. He
seemed very satisfied with those answers. And of course, you know, we're
going to continue to engage with the governor and the congressional
delegation. This afternoon I'm meeting with members of the state legislator as
well - legislators, as well, too. So it's our commitment.

I've only been secretary of the Navy for 16 weeks. Four of those were
completely consumed by Afghanistan. But I'm here to try to help fix this
problem.

Q: Admiral Gilday, you mentioned something about certification training as
part of the steps as we move forward. And so are you looking at the possibility
that human error might have caused this situation?

ADM. GILDAY: We're leaving nothing on the table with respect to exhaustively
looking at both materiel and personnel with respect to what got us to where we
are. Right now we're not satisfied with where we are, clearly. That's why we
launched another investigation. That's why we set up a taskforce to get after
this, a joint taskforce that does include the Board of Water Supply and the
Department of Health. And so we have - we have work to do.

I would - to add on to what the secretary said about the meeting with the
governor, I would just describe that discussion simply as candid and
respectful.

MODERATOR: All right. We'll come to Civil Beat and Christina for our last
question.

Q: All right. So my first question is about monitoring. It seems to me that the
Navy either knew there was a problem with the water and didn't tell people or,
maybe worse, it didn't know there was a problem. Which is it?

REAR ADM. CONVERSE: Which - what timeframe are you referring to?

Q: In the days before people started reporting that they were sick, did any of
you know that there was a problem and not inform people? Or did you not
know that it was coming?

REAR ADM. CONVERSE: We did not know that there was a problem with the
water in the days leading up. And then our first indication were the complaints

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

10/12

-------
we started piecing together individual complaints. Initially started as I have a

were seeing those first indications by the evening of Sunday, there was enough
concern that we said, you know, that the closest water supply to this issue is
the Red Hill shaft, and we have two water supplies normally on service so we
can shift over and take that out of service to eliminate one possible cause of
this. And we did that.

Q: And then -

SEC. DEL TORO: So my understanding - correct me if I'm wrong - is that there
was very little time, actually, between the time that we started receiving
notifications, we did our investigatory work to the point where we shut the Red
Hill shaft down, basically.

REAR ADM. CONVERSE: Yes, sir. That was done that evening and on Sunday
was our first reported indications of contamination in the water supply.

Q: Just to follow up on that, a second question about whether you believe
you're accountable to the state of Hawaii. If Governor Ige tomorrow ordered
de-fueling and a closure of the facility permanently, would you follow that
order?

SEC. DEL TORO: Well, I would definitely take it - in fact, there was a press
release that was released by the governor and the delegation, and I'm taking
that request and their suggestions very seriously. And -

Q: Is it a request, sir, or is it an order? What do you consider it?

SEC. DEL TORO: It's not an order. It's a request that's being made. And we're
taking that very, very seriously, and we're engaging in a series of conversations
before I decide to take actions, like I said, in the next 24 to 48 hours.

MODERATOR: All right, everybody. Thank you so very much for your time
today.

Q: Sorry, can I ask a clarification question? It's important. For November 27th
SEC. DEL TORO: Yes, ma'am.

Q: - that was the temporary suspension of the Red Hill fuel operations.
SEC. DEL TORO: Yes, sir.

a

4S.

Skip to main content (Press Enter).

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

11/12

-------
Q: So, since the governor and the congressional team requested - made the

I

]

Search

SEC. DEL TORO: So we had ceased operations internally, essentially, regarding
the transfer of fuel inside the Red Hill facility. The request that the governor
and the congressional delegation have made is that we cease operations at
Red Hill on a more permanent basis, basically, until we continue, you know, to
discover other facts. And so there's the investigation that we also need to
figure out, as well, too, but I'll be making decisions in the next 24 to 48 hours as
to what my next step will be. And I'm doing it because I want to talk to other
organizations, including state legislators and other individuals here on the
island of Oahu before I gather all the necessary information that I need to
make so that I make the right decision and ensure that there is no secondary
consequences that go unnoticed, as well, too.

MODERATOR: All right, everybody. Thank you so much for your time today.
We appreciate it.

Q: Thank you.

SEC. DEL TORO: Thank you.









Q: Thank you, sir.









<

SHARE

PRINT



RSS



NEWS j

PR



•



News Stories

Press Releases

Statements

Speeches

Testimony

Select Language

Powered by Google Translate

Google Translation Disclaimer

https://www.navy.mil/Press-Office/Press-Briefings/display-pressbriefing/Article/2865118/cno-secnav-and-deputy-commander-of-us-pacific-fleet-speak-during-press-conferen/

12/12

-------
STATE OF HAWAI'I
DEPARTMENT OF HEALTH
SOLID AND HAZARDOUS WASTE BRANCH
UNDERGROUND STORAGE TANK SECTION

EMERGENCY ORDER

TO: THE UNITED STATES DEPARTMENT OF THE NAVY,

Docket No. 22-UST-EA-01

c/o REAR ADMIRAL TIMOTHY J. KOTT,



COMMANDER, NAVY REGION HAWAII,

Re: Emergency Change-ln-Service,



Defueling, and Closure of 20

850 Ticonderoga St., Suite 110

Underground Storage Tanks,

JBPHH, Hawai'i 96860-5101,

Surge Tanks, and Associated



Piping, Red Hill Bulk Fuel

Respondent.

Storage Facility

This Emergency Order ("EO") is an administrative action initiated pursuant to chapters 91 and 342L of the
Hawai'i Revised Statutes ("HRS") and chapters 11-1 and 11-280.1 of the Hawai'i Administrative Rules
CHAR") by the DEPARTMENT OF HEALTH (the "Department") against THE UNITED STATES
DEPARTMENT OF THE NAVY, c/o REAR ADMIRAL TIMOTHY J. KOTT, COMMANDER, NAVY
REGION HAWAII (the "Respondent") and is based upon recent events and upon an ongoing emergency
associated with the Red Hill Bulk Fuel Storage Facility (the "Red Hill Facility" or "Facility"). Respondent is
the owner and operator of the Red Hill Facility. This EO concerns only the issues identified herein and
does not function to preclude or limit actions by any public agency or private party. The Department
reserves the right to bring other actions as may be necessary to protect public health and the
environment (including, but not limited to, actions related to remediation and/or cost recovery).

The Department issued an emergency order, Docket No. 21-UST-EA-02, dated December 6, 2021 (the
"First EO"), which, at the conclusion of a contested case and final decision of Deputy Director Marian
Tsuji upon a full review of the record in that proceeding, became a final order of the Department on
January 3, 2022 (the "First EO Final Order"). The First EO and First EO Final Order are withdrawn
pursuant to HAR §11-1-21(c) and replaced and superseded by this EO.

I. AUTHORITY AND BACKGROUND

Statutes Section 342L-9, HRS, states as follows:

& Rules	§342L-9 Emergency powers; procedures.

(a)	Notwithstanding any other law to the contrary, if the governor or the director
determines that an imminent peril to human health and safety or the environment
is or will be caused by:

(1)	A release;

(2)	Any action taken in response to a release from an underground
storage tank or tank system; or

(3)	The installation or operation of an underground storage tank or
tank system;

that requires immediate action, the governor or the director, without a
public hearing, may order any person causing or contributing to the
peril to immediately reduce or stop the release or activity, and may take any and
all other actions as may be necessary. The order shall fix a place and time, not
later than twenty-four hours thereafter, for a hearing to be held before the director.

(b)	Nothing in this section shall be construed to limit any power which
the governor or any other officer may have to declare an emergency and act on

Page 1 of 9

-------
Docket No. 22-UST-EA-01



the basis of such declaration, if such power is conferred by statute or
constitutional provision, or inheres in the office.

Imminent
Peril and
Findinas of
the

Deoartment

A. The Red Hill Facility, as configured and operated by Respondent, poses an
imminent and ongoing peril to human health and safety and the environment.
The 20 underground bulk fuel storage tanks ("20 Tanks") at the Red Hill
Facility must be safely and expeditiously defueled and the 20 Tanks and their
associated four surge tanks and piping system(s) closed in accordance with
chapter 11-280.1, HAR. To address the imminent and ongoing peril to human
health and safety and the environment presented by the Red Hill Facility, the
defuelina of the Facilitv must be completed at the earliest date consistent with
safe defueling.

On November 20, 2021, a release of fuel occurred at the Red Hill Facility. Respondent
reported a release and recovery of approximately 14,000 gallons of a mixture of fuel and
water from the fire-suppression drain system at the Red Hill Facility.

By November 28, 2021, Respondent had received complaints from water users from
Respondent's water system regarding a gas or fuel odor from their drinking water.

On or about December 2, 2021, Respondent identified the source of fuel contamination
to be the Red Hill Shaft, one of the drinking water sources that services Respondent's
water system.

By December 3, 2021, the Department had received nearly 500 complaints, mostly from
residents or customers serviced by Respondent's water system complaining of fuel or
chemical smell from their drinking water.

On December 6, 2021, the Department issued an EO that included five directives to
Respondent (the "First EO"). A copy of the First EO is attached hereto as Exhibit A.

Following an evidentiary hearing, a Hearings Officer appointed by the Department issued
a proposed decision and order, findings of fact ("FOF"), and conclusions of law ("COL")
(collectively, the "FOF/COL") upholding the First EO. The Hearings Officer's findings
and conclusions included, inter alia, the following:

•	"A release that has already occurred that has damaged human health or the
environment and that is not resolved to DOH's satisfaction constitutes 'an imminent
peril to human health and safety or the environment.'" (COL If 18).

•	"Historical releases have adversely impacted the environment as is evidenced by
detection of fuel and fuel constituents in the Navy's drinking water supply, the
groundwater under the Red Hill Facility, and the soil vapor monitoring probes in the
rocks beneath the facility." (FOF If 30).

•	"The Red Hill Facility, as currently configured and operated, constitutes an imminent
peril to human health and safety or the environment." (COL If 35).

•	"[T]he November 2021 Release caused a humanitarian and environmental
emergency and disaster." (FOF If 39).

•	"Continued operation of the Red Hill Facility, as it is currently configured and
operated, poses an imminent threat to human health and safety or the environment."
(FOF If 59).

•	"More releases of fuel from the Red Hill facility are basically inevitable." (FOF If
62(a)).

•	"The Red Hill USTs have a history of leaking and will continue to leak." (FOF If
62(b)).

Page 2 of 9

-------
Docket No. 22-UST-EA-01

•	"The probability of an acute leak of 1,000 to 30,000 gallons of fuel each year is at
least 27%, which is likely an understated percentage." (FOF If 62(c)).

•	"The probability of a sudden release of more than 120,000 gallons of fuel in the next
100 years is at least 34%, which is likely an understated percentage." (FOF If 62(d)).

•	"The expected volume of chronic, undetected fuel releases from the Red Hill Facility
is at least 5,803 gallons per year." (FOF If 62(e)).

•	"The Navy cannot prevent future releases at the Red Hill Facility." (FOF If 62(f)).

•	"Breaches will continue to occur at the Red Hill Facility." (FOF If 62(g)).

•	"The Red Hill Facility is nearing the end of its life and has reached the 'end-of-life'
phase." (FOF If 62(h)).

•	"The Navy obviously does not want the Red Hill Facility to release fuel, and the Navy
is trying to prevent releases. But despite everything the Navy is attempting to do, it is
not enough: the evidence shows that the Red Hill Facility is simply too old, too poorly
designed, too difficult to maintain, too difficult to inspect, along with being too large to
realistically prevent future releases. It is not just one problem but a combination of
many." (FOF If 71).

•	"[T]he situation is beyond the Navy's ability to adequately mitigate the threats posed
by the continued operation of the Red Hill Facility, with USTs filled with fuel, at this
time." (FOF If 73).

•	"The threat of future releases poses an imminent peril to human health and safety or
the environment at large." (FOF If 74)

•	"The presence of fuel in the Red Hill USTs is an ongoing threat to human health and
safety or the environment, given these problems." (FOF If 84).

•	"The weight of the evidence establishes that the Red Hill Facility, as currently
situated, is a metaphorical ticking timebomb located 100 feet above the most
important aquifer on Hawaii's most populous island. The Red Hill Facility has already
damaged human health and the environment and, as currently situated, inevitably
threatens to do so into the future. The Navy lacks the ability to control the substantial
risks associated with the Red Hill Facility, as currently situated." (FOF If 105).

•	"That the Red Hill Facility, as currently constituted, poses an imminent peril to human
health and safety or the environment is a fact established by a preponderance of the
evidence." (FOF If 106).

A copy of the Hearings Officer's FOF/COL is attached hereto as Exhibit B.

In the First EO Final Order entered on January 3, 2022, the FOF/COL issued by the
Hearings Officer were (in all relevant respects) sustained and adopted as the final
decision, order, findings of fact and conclusions of law of the Department. A copy of the
First EO Final Order is attached hereto as Exhibit C. The factual findings set forth in the
FOF/COL and adopted in the First EO Final Order, together with the administrative
record generated in connection with Docket No. 21-UST-EA-02, are hereby incorporated
by reference and have been relied upon by the Department in issuing this EO.1

1 On February 2, 2022, the United States, on behalf of Respondent, filed an appeal of the First EO Final
Order in the State Environmental Court of the First Circuit (1CCV-22-0000142), and filed a federal action
challenging the EO in the Federal District Court (1:22-cv-00051 DKW-RT). Those challenges were
dismissed with prejudice on April 22, 2022 (state appeal) and April 25, 2022 (federal action), respectively.

Page 3 of 9

-------
Docket No. 22-UST-EA-01



B. Respondent acknowledges the need to safely defuel and permanently close
the 20 Tanks, 4 surge tanks, and associated piping system(s).

On March 7, 2022, Secretary of Defense Lloyd J. Austin III issued a memorandum
directing "the Secretary of the Navy, in coordination with the Commander of the United
States Indo-Pacific Command, to take all steps necessary to defuel and permanently
close the Red Hill Bulk Fuel Storage Facility[.]" That memorandum further states that,
"[b]y no later than May 31, 2022, the Secretary of the Navy and Director, [Defense
Logistics Agency] will provide [the Secretary of Defense] with a plan of action with
milestones to defuel the facility," and that "[t]he plan of action shall require that defueling
operations commence as soon as practicable after the facility is deemed safe for
defueling and target the completion of that defueling within 12 months." A copy of
Secretary Austin's memorandum is attached hereto as Exhibit D.

On April 4, 2022, the United States entered into a stipulation between and among all
parties to the action in federal court (1:22-cv-00051 DKW-RT) in which the United States
committed that it "will defuel and permanently close the twenty Underground Storage
Tanks at the Red Hill Bulk Fuel Storage Facility . . . and the pipelines that are ordinarily
used to transport fuel between these tanks and the underground pumphouse." A copy is
attached hereto as Exhibit E.

On April 20, 2022, Respondent issued a letter to the Department withdrawing their UST
permit application for the Facility on the basis that they intend to "defuel and close the 20
underground storage tanks at Red Hill, the pipelines ordinarily used to transport fuel
between the tanks and the underground pumphouse, and the four surge tanks and their
appurtenant piping." A copy is attached hereto as Exhibit F.

Backaround
/ Context

On January 13, 2014, Respondent discovered a loss of fuel from Tank #5 of its 20 Tanks
at the Facility and immediately notified the Department and the United States
Environmental Protection Agency ("EPA") (collectively, the "Regulatory Agencies"). On
January 16, 2014, Respondent verbally notified the Regulatory Agencies of a confirmed
release of a regulated substance from Tank #5. On January 23, 2014, Respondent
provided written notification to the Department. Respondent estimated the fuel loss at
approximately 27,000 gallons.

In 2015, Respondent, the Defense Logistics Agency, and the Regulatory Agencies
entered into an Administrative Order on Consent (the "AOC") to take steps to ensure that
the groundwater resource in the vicinity of the Facility is protected and to ensure that the
Facility is operated and maintained in an environmentally protective manner.

On March 17, 2020 and June 2, 2020, Respondent notified the Department of a release
of a regulated substance to surface water at Hotel Pier. In a letter dated June 30, 2021,
the Department made the determination that a release occurred from the Facility.

On May 7, 2021, Respondent reported a pipeline release of a regulated substance that
occurred on May 6, 2021 that released approximately 1,000 gallons of fuel, of which a
significant portion was recovered. Based on Respondent's report of Root Cause
Analysis of the JP-5 Pipeline Damage, dated September 7, 2021, the pipeline releases
near Tanks #18 and #20 were due to a dynamic transient surge resulting from the
Control Room Operator failure to follow the valve opening and closing sequence.
Respondent estimated the amount of JP-5 released in the lower Red Hill Tunnel was
1,618 gallons, of which 1,580 gallons were recovered. Respondent reported that
38 gallons were unaccounted for and, therefore, released into the environment.

On July 23, 2021, Respondent submitted a confirmed release notification form that
indicated that approximately 150 gallons of a regulated substance was released at Kilo
Pier in a boomed area of the surface water. Approximately 110 gallons were recovered.

Page 4 of 9

-------
Docket No. 22-UST-EA-01

On November 9, 2021, the Department was informed by the media of another surge
event that occurred on September 29, 2021. After an inquiry by the Department, on
November 12, 2021, Respondent asserted on November 17, 2021 that no release
occurred during the event.

On April 1, 2022, the Department was notified by the Navy of a suspected release of
approximately 30 gallons of a fuel and water mixture from a maintenance line connected
to Tank #14 at the Red Hill Bulk Fuel Storage Facility. This release reportedly occurred
during maintenance work to remove water from the underground storage tanks, an
environmental control measure to avoid corrosion in the tanks. Release to the
environment was not confirmed.

II. ORDER

Respondent is hereby ordered to:

1.	Maintain the suspension of operations as previously directed by the First EO and First EO Final
Order, including, but not limited to, fuel transfers at the 20 Tanks at the Red Hill Facility.
Respondent must maintain environmental controls, release detection and release response
protocols in compliance with all applicable laws and regulations. Maintenance shall be performed
to the extent necessary to prepare for and safely support defueling and UST system closure, and
to prevent an additional release between the date of this EO and the date on which the 20 Tanks,
4 surge tanks, and associated piping system(s) are permanently closed.

2.	Consistent with Directive #2 set forth in the First EO and First EO Final Order, continue to
maintain the groundwater treatment system(s) at Red Hill Shaft to minimize movement of
contaminant plume(s). Continue to take steps to recover the Red Hill Shaft to drinking water
quality. If Respondent identifies the Red Hill Shaft as a drinking water source, develop an
appropriate water treatment and monitoring system that conforms to the standards prescribed by
the Safe Drinking Water Act, applicable regulations, and State guidance. Any water treatment
system(s) must be reviewed and approved by the Department prior to installation and operation.

3.	Within 7 calendar days following Respondent's receipt of this EO, Respondent must submit a
copy of the Assessment Report under NAVSUP FLC Norfolk Contracting, Contract No.
N0018922P0080P00001 (the "Assessment Report") to the Department. A redacted version must
also be submitted to the Department as soon as practicable following the date on which the
unredacted document is submitted to the Department, not later than 10 business days following
the date on which the unredacted document is submitted to the Department. See 10 U.S.C.
§130e; chapter 92F, HRS; chapter 2-71, HAR.2 Within 7 calendar days following Respondent's
submittal of the Assessment Report to the Department, Respondent must meet and confer with
Department staff to address Respondent's plan for the implementation of the Assessment
Report's recommendations. Additionally, within 7 calendar days following Respondent's receipt
of this EO (and on a rolling basis thereafter as additional documents are provided to the EPA),
Respondent must transmit to the Department copies of the information and documents provided
by Respondent to the EPA in response to the EPA's Request for Information dated April 25, 2022
(EPA DKT NO. RCRA 7003-R9-2015-01). Redacted versions of these documents must also be
submitted to the Department as soon as practicable following the date on which the unredacted
documents are submitted to the Department, not later than 10 business days following the date
on which the unredacted documents are submitted to the Department. See 10 U.S.C. §130e;

2 The Department may, in its discretion and by agreement between Respondent and the Department,
grant reasonable extensions of time with respect to submittals of documents required under this EO.
Respondent must, however, establish that good cause exists to warrant such extensions.

Page 5 of 9

-------
Docket No. 22-UST-EA-01

chapter 92F, HRS; chapter 2-71, HAR.

4. Respondent must submit to the Department a phased plan for defueling and permanently closing
the Red Hill Facility (the "Closure Plan") to achieve the completion of defueling at the earliest date
consistent with the safe defueling of the Facility. Defueling must occur in a manner that is
evidence-driven and supported by data and studies of the Facility, and consistent with the
recommendations of subject matter experts. The Closure Plan must be provided to the
Department in two phases: (1) the Defueling Phase and (2) the Closure Phase. The Defueling
Phase of the Closure Plan, including an implementation schedule, must be provided to the
Department no later than June 30. 2022. Redacted versions of these documents must also be
submitted to the Department as soon as practicable following the date on which the unredacted
documents are submitted to the Department, not later than 10 business days following the date
on which the unredacted documents are submitted to the Department. See 10 U.S.C. §130e;
chapter 92F, HRS; chapter 2-71, HAR. The Defueling Phase of the Closure Plan may
incorporate the provisions and recommendations of the Assessment Report.

In determining whether, in its discretion, to approve, approve in part, conditionally approve, or
disapprove the Defueling Phase of the Closure Plan, the Department will consider whether the
plan adequately incorporates, at a minimum, the following:

a.	A detailed description of the information reviewed and gathered, with appropriate
references.

b.	The specific procedures to defuel the 20 Tanks, four surge tanks, and associated
pipelines, including, but not limited to, the sequence in which the tanks are planned to be
emptied, the proposed process, and a general description of the fuel-transfer destination
(e.g., pier, above-ground storage tank, etc.). A description of the infrastructure and
procedures needed to perform the work and ensure pipeline integrity (i.e., identify the
specific pipelines, receiving surge tanks and storage tanks, tanker vessel, truck loading
racks, pier, etc.).

c.	A detailed description of assessment work performed (e.g., the hazard and operability
study and risk assessment, field work with data provided), evaluations performed (e.g.,
tank and pipeline analysis), and the design standards utilized to determine infrastructure
integrity (including, but not limited to, piping, associated valves, piping connections, and
pumps) to perform the work outlined in the Defueling Phase of the Closure Plan.

d.	A description of the Assessment Report's findings and recommendations on correcting
deficiencies or areas that require repair or changes to ensure safe defueling, and the
basis for those findings and recommendations. Necessary repairs to all regulated UST
facility pipelines must comply with HAR §11-280.1-33(a)(5) and must be completed prior
to defueling (with associated records per HAR §11-280.1-33(b) submitted to the
Department).

e.	An explanation of how the Assessment Report's recommendations will be incorporated
and what quality assurance and quality control steps will be adopted or implemented to
ensure that any and all necessary repairs will be performed in accordance with the
recommendations and industry best practices prior to defueling.

f.	Plans for oil spill/release prevention, containment, and response/contingency plans,
including the deployment of resources sufficient to adequately respond to and clean up
any releases that occur during the defueling process.

g.	Prioritization and proposed implementation schedule, including detailed critical path, for
necessary repairs and defueling. It is essential that the implementation schedule achieve
the defueling of the Red Hill Facility at the earliest date consistent with the safe defueling
of the Facility and the protection of public health and the environment. If Respondent
certifies to the Department that defueling of the Bulk Fuel Storage Tanks at the Red Hill
Facility cannot safely be achieved within 30 calendar days in a manner that protects

Page 6 of 9

-------
Docket No. 22-UST-EA-01

public health and the environment, defueling of the Bulk Fuel Storage Tanks at the
Facility must nevertheless be completed at the earliest date consistent with safe
defueling and the protection of public health and the environment. This is necessary to
address the ongoing and imminent peril to human health and safety and the environment
posed by the Red Hill Facility, and the implementation schedule set forth in the Defueling
Phase of the Closure Plan must reflect this requirement.

5.	The Department will assess and evaluate the Defueling Phase of the Closure Plan on an
expedited basis upon receipt. The Department may, in its discretion, approve, disapprove, or
conditionally approve the Defueling Phase of the Closure Plan (in whole or in part). Upon the
Department's approval of the Defueling Phase of the Closure Plan, Respondent must
immediately begin implementation in accordance with the approved implementation schedule,
including, but not limited to, performing necessary repairs and changes to cure any impediments
to the safe and expeditious defueling of the Facility identified therein. Should the Department
disapprove any portion of the Defueling Phase of the Closure Plan, the Department will upon
disapproval identify the basis for the disapproval and require Respondent to submit a further
response by a specified date.

6.	With respect to the list of documents provided to the contractor performing the work under
Directive #3 and as requested in EPA's Request for Information dated April 25, 2022,
Respondent must provide the Department access to all such documents, materials, and
information, upon the Department's request. If information was provided under direction of the
contractor, Respondent must also submit to the Department copies of the associated information
requests. The provision of this information to the Department is essential to facilitate the
Department's timely and effective assessment of the Defueling Phase of the Closure Plan.
Redacted versions of these documents must also be submitted to the Department as soon as
practicable following the date on which the unredacted documents are submitted to the
Department, not later than 10 business days following the date on which the unredacted
documents are submitted to the Department. See 10 U.S.C. §130e; chapter 92F, HRS; chapter
2-71, HAR.

7.	In accordance with the approved schedule, and upon the commencement of defueling,
Respondent must submit to the Department weekly situation reports or briefings outlining
Respondent's progress toward safe and complete defueling of the Red Hill Facility. The above-
referenced reports or briefings must indicate, with specificity, what activities were undertaken by
Respondent (and what activities are scheduled for the upcoming week by Respondent) in
connection with the defueling of the 20 Tanks, four surge tanks, and associated piping system(s)
at the Facility. Redacted versions of these documents must also be submitted to the Department
as soon as practicable following the date on which the unredacted documents are submitted to
the Department, not later than 10 business days following the date on which the unredacted
documents are submitted to the Department. See 10 U.S.C. §130e; chapter 92F, HRS; chapter
2-71, HAR. Before making any changes to pre-approved planned procedures (i.e., changes to
the Closure Plan), Respondent must discuss the proposed changes and obtain concurrence from
the Department.

8.	Notice of intent to permanently close the Facility having previously been provided to the
Department (see Exhibits D, E, and F, attached hereto), closure of the Facility must occur in
accordance with chapter 11-280.1, HAR. Respondent must comply with all applicable provisions
of state law regarding the closure of the Facility, and the permanent closure of the Facility must
occur in a manner approved by the Department and as set forth in the Closure Phase of the
Closure Plan. On or before July 15. 2022. Respondent shall meet and confer with Department
staff regarding planning and scheduling for Facility closure, and Respondent must thereafter
develop the Closure Phase of the Closure Plan, to be submitted to the Department no later than
November 1. 2022. The Department will assess and evaluate the Closure Phase of the Closure
Plan on an expedited basis upon its receipt. The Department may, in its discretion, approve,
disapprove, or conditionally approve the Closure Phase of the Closure Plan (in whole or in part).
Should the Department disapprove any portion of the Closure Phase of the Closure Plan, the

Page 7 of 9

-------
Docket No. 22-UST-EA-01

Department will upon disapproval identify the basis for the disapproval and require Respondent to
submit a further response by a specified date. In determining whether, in its discretion, to
approve, approve in part, conditionally approve, or disapprove the Closure Phase of the Closure
Plan, the Department will consider whether the plan adequately incorporates, at a minimum, the
following:

Description of the sequence and process in which the tanks and pipelines are planned to
be cleaned, including the four surge tanks and related piping; the infrastructure and
procedures needed to perform the work and ensure pipeline integrity before the cleaning
process; the method of permanent closure (remove, fill, or close in place) and associated
design and process; ultimate disposition of any accumulated sludge or waste material
from the 20 Tanks, four surge tanks, and associated piping; and site assessment in
connection with the Facility's permanent closure.

In addition, Respondent must continue to characterize the release(s) and develop strategies for
remediation of impacted groundwater in accordance with 11-280.1, HAR.

This EO is enforceable immediately upon issuance today, Friday, May 6, 2022. A hearing is scheduled
for May 7, 2022, at 2:00 p.m. HST with the Department's Hearings Officer via Zoom, or other similar
electronic platform (with links to be provided to both Respondent and the public for their participation).
The parties may by mutual agreement reschedule the hearing to a mutually-acceptable date and time. If
you wish to waive your right to contest this EO at a hearing, you may communicate this intention to the
Director of Health, Department of Health, 1250 Punchbowl Street, Third Floor, Honolulu, HI 96813 and to
the Solid and Hazardous Waste Branch, Department of Health, 2827 Waimano Home Road #100, Pearl
City, HI 96782 or by email at Wade.H.Hargrove@hawaii.gov. You must comply with this EO irrespective
of whether a hearing is waived. Per HRS § 342L-9, this EO is and will remain fully in force and effect
pending any contested case hearing associated with this EO, pending the Director's consideration of this
EO and finalization of this EO into a Final Order of the Department, and pending any appeal or other legal
challenge to this EO, unless expressly ordered otherwise by the Department or by a court of competent
jurisdiction.

At the hearing, you may seek to avoid obligations prescribed in this EO, and the Department may seek to
impose any additional obligations necessary to protect public health and the environment. Parties may
present evidence and witnesses on their behalf, and may examine and cross-examine all witnesses and
evidence presented by the Department. Parties may be represented by attorneys at their own expense,
or they may represent themselves. Any hearing will be in accordance with chapter 91, HRS, and chapter
11-1, HAR. The final administrative decision will be made at the conclusion of the hearing and will be
based upon all the evidence presented during the hearing.

/

/

/

/

/

/

/

/

/

Page 8 of 9

-------
Docket No. 22-UST-EA-01

If you have questions, please call Lene Ichinotsubo, P.E., Acting Chief of the Solid and Hazardous Waste
Branch at (808) 586-4226. If you have special needs due to a disability and require accommodation to
aid you in participating in the hearing or pre-hearing conference, please contact the Hearings Officer at
(808) 586-4400 (voice) or through the Telecommunications Relay Service (711).

DATED:	Honolulu, Hawai'i May 6, 2022

DEPARTMENT OF HEALTH
STATE OF HAWAI'I

KATHLEEN S. HO

Deputy Director for Environmental Health

\PPROVE0 AS TO FORM

/VAD/ H. HARGROVE,,"111
De ty Attorney General

Page 9 of 9

-------
DEPARTMENT OF THE NAVY

COMMANDER
NAVY REGION HAWAII
850 TICONDEROGA ST STE 110
JBPHH. HAWAII 96860-5101

JUL 2 2 2

5000-45A
N45

July 16, 2021

CERTIFIED NO: 9489 0090 0027 6232 9870 23

Ms. Roxanne Kwan
Hawaii State Department of Health
Solid and Hazardous Waste Branch
Underground Storage Tank Section
2827 Waimano Home Road #100
Pearl City, HI 96782

Dear Ms. Kwan:

SUBJECT: NOTIFICATION FOR UNDERGROUND STORAGE TANKS,

RED HILL BULK FUEL STORAGE FACILITY, JBPHH. OAHU,
DOH FACILITY ID NO. 9-102271

As required by Hawaii Administrative Rules 11-280.1-34, the Navy is submitting written
notification for the return to currently-in-use status of Surge Tank 1 (F-ST1). DOH Form No. 1,
Notification for Underground Storage Tanks, is being submitted as Enclosure 1.

Enterprise Engineering, Inc. performed a post-repair inspection of Surge Tank 1 and
determined repairs were completed in accordance with repair design documents. A Suitability of
Service Testament for Surge Tank 1 is being submitted as Enclosure 2.

A leak detection test was conducted on Surge Tank 1 with passing results. The tank tightness
test summary is being submitted as Enclosure 3. In accordance with Exemption (b) of the
Freedom of Information Act, the name of the subcontractor who performed the leak detection
test has been redacted.

If you have any questions regarding this matter or need any additional information, contact

(b) (6)

Sincerely,

(b) (6)

Director

Regional Environmental Department

By direction of the

Commander

-------
DEPARTMENT OF THE NAVY
COMMANDER
NAVY REGION HAWAII
850 TICONDEROGA ST STE 110
JBPHH, HAWAII 96860-5101

MAY 2 f 2020Cj^

5750

Ser N4/00258
20 May 20

CERTIFIED NO: 7019 2970 0001 7433 3530

Ms. Roxanne Kwan
Hawaii State Department of Health
Environmental Management Division
Solid and Hazardous Waste Branch
Underground Storage Tank Section
2827 Waimano Home Road #100
Pearl City, HI 96782

Dear Ms. Kwan:

SUBJECT: NOTIFICATION FOR UNDERGROUND STORAGE TANKS, RED HILL BULK
FUEL STORAGE FACILITY, JBPHH, OAHU, DOH FACILITY ID
NO. 9-102271

As required by Hawaii Administrative Rules 11-280.1-34, the Navy is submitting written
notification for the return to currently-in-use status of Tank 5 (F-5) and Surge Tank 4 (F-ST4),
and the temporary closure of Tank 18 (F-18) and Surge Tank 3 (F-ST3). DOH Form No. 1,
Notification for Underground Storage Fanks. is being submitted as Enclosure 1.

Enterprise Engineering, Inc. (EEI) performed a post-repair inspection of Tank 5 and
determined repairs were completed in accordance with repair design documents. A Suitability of
Service Testament for Tank 5 is being submitted as Enclosure 2.

Tank tightness testing was completed during the filling of Tank 5 when fuel reached the 70-
foot, 110-foot, 150-foot and 202-foot levels in the tank. Each tank tightness test consisted of
monitoring the tank for 24 consecuti ve hours over five straight days. Tank 5 passed each of the
tank tightness tests at each level. The executive summary of the leak detection testing report is
being submitted as Enclosure 3. In accordance with Exemption (b)(4) of the Freedom of
Information Act, the name of the subcontractor who performed the leak detection test has been
redacted.

EEI performed a post-repair inspection of Surge Tank 4 and determined repairs were
completed in accordance with repair design documents. A Suitability of Service Testament for
Surge Tank 4 is being submitted as Enclosure 4.

A leak detection test was conducted on Surge Tank 4 with passing results. The executive
summary of the leak detection testing report is being submitted as Enclosure 5. In accordance
with Exemption (b)(4) of the Freedom of Information Act, the name of the subcontractor who
performed the leak detection test has been redacted.

-------
5750

Ser N4/00258
20 May 20

If you have any questions regarding this matter or need any additional information, contact

| or by email at||

Enclosures: 1. DOH Form No. 1, Notification for Underground Storage Tanks for Red Hill

Bulk Fuel Storage Facility, JBPHH, Oahu, DOH Facility ID No. 9-102271

2.	Suitability for Service Testament for Tank 5, prepared by Enterprise
Engineering, Inc., 08 Jan 2020

3.	Executive Summary, 2020 Leak Detection Testing Report of Bulk Field-
Constructed Underground Storage Tank 5 at Red Hill Fuel Storage Complex,
submitted by Michael Baker International, 30 Apr 2020 (Redacted)

4.	Suitability for Service Testament for Surge Tank 4 (Facility No. 1227), prepared
by Enterprise Engineering, Inc., 08 Jul 2020

5.	Executive Summary, 2019 Annual Leak Detection Testing Report of 17 Bulk
Field-Constructed Underground Storage Tanks at Red Hill Fuel Storage
Complex, submitted by Michael Baker International, 08 Jan 2020 (Redacted)

Copy to: U.S. Environmental Protection Agency Region 9
Commander, Navy Region Hawaii
Navy Facilities Engineering Command, Hawaii

U.S. Naval Supply Systems Command Fleet Logistics Center Pearl Harbor

M. R. DELAO
Captain, CEC, U.S. Navy
Regional Engineer
By direction of the
Commander

2

-------
SOLID AND HAZARDOUS WASTE BRANCH
Underground Storage Tank Program

2827 Waimano Home Road #100 • Pearl City, Hawaii 96782
Phone: 808 - 586- 4226 • Fax: 808-586-7509 • http://www.hawaii.gov/heaIth/environmentalAvaste/ust

NOTIFICATION FOR UNDERGROUND STORAGE TANKS

Return completed form to:

Solid and Hazardous Waste Branch
Underground Storage Tank Program
2827 Waimano Home Road #100
Pearl City, Hawaii 96782

Facility ID Number: 9- 02271

State Use Only

Date received:

Date Entered into Computer:

Permit Number:

Type of Notification/s: (Check all that apply)

[S. UST Status Change (temporary or permanent closure or return to use)
	Change in Piping

IH Change in Spill and/or Overfill Prevention Method

	Change in Release Detection Method

CZ Change in Financial Responsibility Mechanism

IZHother:

Comments:

Date Activity Occurred: °,W0'2020i<«»i.i«ii««.ti«w>.

Location Address (P.O. Box not acceptable) City State Zip Code Island Tax Map Key#

(808)473-7801

(808)473-7815

Location Phone # (w/ area code)

Location Fax # (w/ area code)



II. CONTACT PERSON IN CHARGE OF TANK(S)

Regional Fuels Officer

Name

Job / Position Title

i w uanney btreei.

JBPHH HI 96860

Mailing Address

City State Zip Code



(808)4/3-/816

Phone # (w/ area code)

Fax # (w1 area code) E-mail Address

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 1 of 33

^CLOSURE* J )

-------
Facility ID No. 9-102271

III. OWNER OF TANK(S)

US Navy - COMNAVREG HI

Owner Name (Corporation, Individual, Public Agency, or Other Entity)







850 Ticonderoga Street, Suite 110

JBPHH

HI

96860

Mailing Address

City

State

Zip Code

(808)471-3926 (808)473-5024



marc.delao@navy.mil



Phone # (w/area code)	Fax # (w/area code)	E-mail Address

IV. OPERATOR OF TANK(S) (if same as Section III, check here Q )

Naval Supply Systems Command Fleet Logistics Center Pearl Harbor

Operator Name (Corporation, Individual, Public Agency, or Other Entity)







1942 Gaffney Street,

JBPHH

HI

96860

Mailing Address

City

State

Zip Code

(808)473-7815





¦

Phone # (wI area code)	Fax # (wI area code)	E-mail Address

V. TYPE OF FACILITY (Select the appropriate facility description)

~	Airline

~	Auto Dealership
CD Baseyard

~	Car Rental

~	Cleaner/Laundromat

~	Communication Sites

[HI Contractor
IIFarm
EIlFire Station
ED Gas Station
(ZZlcolf Course
ED Hospital

EH Petroleum Distributor
~ Police Station
EH Residential
ED Resort/Hotel
EH School

~ Service Centers/Auto Repair/Maintenance
I Itruckina/Transoorter
I I Utilities

I I Wastewater Treatment Plants
I I Wholesaler/Retailer

0Other (Explain) Fuel Storage and Airfield Hydrant System

VI. FINANCIAL RESPONSIBILITY (Check all that apply)

~	Commercial Insurance	ED Letter of Credit	I I Local Government Bond Rating Test

~	Financial Test of Self Insurance EDsurety Bond	EDother Method Allowed (Specify)	

~ Guarantee	EHTrustFund	[3 Exempt: EUState or 0 Federal Agency

Checking one or more of the above boxes attests to the fact that the financial responsibility requirements in subchapter 8 of chapter
11-280.1, Hawaii Administrative Rules, are met using the selected mechanism(s) as of the date of the certification below.

Notification for Underground Storage Tanks - Form No. 1	„ , f ,,

Date: 7/16/2018 (rev February 1, 2019)	g 2 0T "

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F-1

Tank No. F'2

Tank No. ^-3

Tank No. F-4

Tank No. ^-5

1. Status of Tank (Mark only one)

A. Currently in Use

~

0

0

0

0

B. Temporarily Out of Use
(Also complete Section XI)

0

~

~

~

~

C. Permanently Out of Use
(Also complete Section XI)

~

~

~

~

~

2. Date of Installation (mo/year)

10/1942

09/1942

01/1943

11/1942

12/1942

3. Estimated Capacity (gallons)

12,000,000

12,000,000

12,000,000

12,000,000

12,700,000

A. Compartmentalized? Yes/No

No

No

No

No

No

Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No ;

4. Substance Currently or Last Stored in Greatest Quantity by Volume

A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A !

D. Kerosene

~

~

~

~

~ I

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 3 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"1

Tank No. F"2

Tank No. F-3

Tank No. F"4

Tank No. F-5

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

EMPTY

F-24

F-24

F-24

F-24

5. Substance Compatible with
Tank and Piping? Yes/No

N/A

Yes

Yes

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

0

0

0

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

13

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 4 of3B

-------
Facility ID No. 9-102271

Tank Number

Tank No.

Tank No. ^-2

Tank No. ^

Tank No. ^-4

Tank No. ^-5

C. Primary Containment Material or Single-Wailed Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

13

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

[Z

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

13

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

0

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

13

0

~

0

0

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February I, 2019)

Page 5 of 3B

-------
Facility ID No. 9-102271

Tank Number

Tank No. F-1

Tank No. F-2

Tank No. F-3

Tank No. F-4

Tank No. F-5

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

~

NA

0

NA

0

NA

0

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - form No. 1
Date: 7/16/2018 (rev February 1, 2Q19|

Page 6 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F-1

Tank No. F-2

Tank No. F-3

Tank No. F-4

Tank No. F-5

1. Closing ofTank

A. Estimated date last used
{mo./day/year)

N/A

N/A

N/A

N/A

N/A

B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











j 3. Evidence of a Leak Detected (Y/N)











Tank Number

Tank No. fzi

Tank No. F-2^

Tank No.

Tank No. F-4

Tank No. F-5 [

A. Date Repaired

N/A

N/A

N/A

N/A

01/13/2020

B. Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



Tank F-5:











Contractor completed a comprehensive out-of-service internal integrity inspection and repair ofTank 5. Completed shell repairs
included weld repairs, patch plate repairs, pipe cap repairs, weld repairs after grinding. Based on inspection of the repairs and
review of documentation of the repairs, the Engineer of Record determined Tank 5 is suitable to return to service, as specified
in the Contractor's Suitability for Sen/ice Testament (attached).

Leak detection testing ofTank 5 was performed at four (4) different product levels, with no detectable leak above the test
method's minimum detectable leak rate, resulting in passing tests. The leak detection testing conducted meets the regulatory
requirements in HAR 11 -280.1-43(10). The Executive Summary of the 2020 Leak Detection Testing Report of Bulk Field-
Constructed Underground Storage Tank 5 at Red Hill Fuel Storage Complex is attached.

C. Select one of the following:

N/A

N/A

N/A

N/A

N/A

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.

N/A

N/A

N/A

N/A

Yes ;

iii. Manufacturer's installation
checklists have been completed
and documented

N/A

N/A

N/A

N/A

N/A ;

iv. Another method allowed by the
department. Please specify

N/A

N/A

N/A

N/A

N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 7 of33

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification ofstreets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. ^-6

Tank No. F-7

Tank No

Tank No. F"9

Tank No. F"10

1.

Status of Tank (Mark only one)











A. Currently in Use

0

0

0

0

0

B. Temporarily Out of Use
(Also complete Section XI)

~

~

~

~

~

C. Permanently Out of Use
(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

12/1942

05/1943

03/1943

02/1943

01/1943

3.

Estimated Capacity (gallons)

12,700,000

12,700,000

12,700 000

12,700,000

12,700,000



A. Compartmentataed? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 8 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F-6

Tank No. F"7

Tank No. F-8

Tank No. F"9

Tank No. F"10

E. Used Oil/Waste Oil

~

~

~

" ~

~

F. JP^

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-24

JP-5

JP-5

JP-5

JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

0

0

0

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

13

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 9 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. f"®

Tank No. ^-7

Tank No.

Tank No.

Tank No,F"10

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

El

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

13

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

0

13

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

~

0

/

0

0

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 10 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"6

Tank No. F"7

Tank No.

Tank No. F"9

Tank No.F"10

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

0

NA

0

NA

0

NA

0

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A

If YES, specify type.











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

NA

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 11 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE	

Tank Number

Tank No. F-6

Tank No. F-7

Tank No. F-8

Tank No. F-9

Tank No. F"10

1. Closing ofTank

A. Estimated date last used
(mo./day/year)

N/A

N/A

N/A

N/A

N/A

B.

Estimated date tank closed
(mo. /day/year)











C.

Tank was removed from ground











D.

Tank was closed in ground











E.

Tank filled with inert material
Describe











F.

Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No, F-6

Tank No. F"7

Tank No. F-8

Tank No. F-9

Tank No. p-1Q

A.

Date Repaired

N/A

N/A

N/A

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department, please specify











Notification for Underground Storage Tanks - Form No. 1	Paee 12 of 33

Date: 7/16/2018 (rev February 1, 2019)

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F"11

Tank No. F'12

Tank No.

Tank No. F"14

Tank No.

1.

Status of Tank (Mark only one)











A. Currently in Use

0

0

~

~

0

B. Temporarily Out of Use
(Also complete Section XI)

~

~

0

0

~

C. Permanently Out of Use
(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

02/1943

03/1943

03/1943

03/1943

04/1943

3.

Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 13 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"11

Tank No. F'12

Tank No. F"13

Tank No. F"14

Tank No. F"15

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

JP-5

JP-5

EMPTY

EMPTY

F-76

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

N/A

N/A

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

0

0

0

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

~

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 14 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"11

Tank Nd.^12

Tank No. F_13

Tank No. F"14

Tank No. F"15

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

0

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

0

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

13

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

13

0

~

0

0

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 15 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F'11

Tank No. F"12

Tank No.F"13

Tank No. F~14

Tank No. F"15

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

13

NA

0

NA

0

NA

0

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 16 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE

Tank Number

Tank No. F"11

Tank No. F"12

Tank No. F'13

Tank No. F_14

Tank No. F"15

1. Closing of Tank

A. Estimated date last used
(mo./day/year)

N/A

N/A

N/A

N/A

N/A

B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F_11

Tank No. F"1?

Tank No, F"13

Tank No. F"14

Tank No. F-15

A.

Date Repaired

N/A

N/A

N/A

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F"16

Tank No. F"17

Tank No F"18

Tank No. F"19

Tank No. F~20

1.

Status of Tank (Mark only one)











A. Currently in Use

0

~

~

~

0

B. Temporarily Out of Use
(Also complete Section XI)

~

0

0

0

~

C. Permanently Out of Use
(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

05/1943

05/1943

05/1943

06/1943

07/1943

3.

Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019|

Page 18 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"16

Tank No. F"17

Tank No. F"18

Tank No. F'19

Tank No. F"20

E. Used Oil/Waste Oil

~

~

Q

D

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-76

EMPTY

EMPTY

EMPTY

JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

N/A

N/A

N/A

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

13

0

0

[3

0

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

13

13

13

0

0

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

n

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 19 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"16

Tank No.

Tank No. F'18

Tank No. p-19

Tank No. F"20

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

/

/

/

/

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

0

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

13

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

0

~

0

0

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 20 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No.F"16

Tank No.JUL

Tank No. F~18

Tank No. F"19

Tank No.F~20

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

12

NA

13

NA

13

NA

~

NA

13

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A

If YES, specify type.











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 21 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE

Tank Number

Tank No. F"16

Tank No. F-17

Tank No. F-18

Tank No. F-19

Tank No. F"20

1. Closing ofTank

A. Estimated date last used
(mo./day/year)

N/A

N/A

05/04/2020

N/A

N/A

B. Estimated date tank closed
(mo./day/year)





07/03/2020





C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)





N/A





3. Evidence of a Leak Detected (Y/N)





No





XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F~16

Tank No. F"17

Tank No. F"18

Tank No. M9

Tank No. F'20

A.

Date Repaired

N/A

N/A

N/A

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form No. 1	p jj *«

Date; 7/16/2018 (rev February 1, 2019)	B

-------
Facility ID No. JM02271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F"ST1

Tank No. F"ST2

Tank No. ^

Tank No. F'ST4

Tank No. ""B

1. Status of Tank (Mark only one)

A. Currently in Use

0

0

~

0

0

B. Temporarily Out of Use
(Also complete Section XI)

~

~

0

~

~

C. Permanently Out of Use
(Also complete Section XI)

~

~

~

~

~

2. Date of Installation (mo/year)

07/1942

07/1942

07/1942

07/1942



3. Estimated Capacity (gallons)

400,000

400,000

400,000

400,000

31,665

A. Compartmentalized? Yes/No

No

No

No

No

No

Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4. Substance Currently or Last Stored in Greatest Quantity by Volume

A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 23 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F'ST1

Tank No. F"ST2

Tank No. F"ST3

Tank No. F"ST4

Tank No. RBC'ta

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-24

JP-5

EMPTY

F-76

F-24, F-76, JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

N/A

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

N/A

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

El

0

13

13

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

13

13

13

13

~

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 24 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"ST1

Tank No. F"ST2

Tank No. F"ST3

Tank No. F"ST4

Tank No. """C

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

/

/

0

0

/

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

0

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

~

~

~

~

0

D. Not Applicable

IZI

0

0

0

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

0

0

0

0

~

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

0

~

0

~

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 25 of SB

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"ST1

Tank No. F'ST2

Tank No. F"ST3

Tank No. F"ST4

Tank No.

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

0

NA

0

NA

0

NA

0

NA

~

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

0

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 26 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE

Tank Number

Tank No. F_ST1

Tank No. F_ST2

Tank No. F_ST3

Tank No. F'ST4

Tank No. pip°hn

1. Closing ofTank

A. Estimated date last used
(mo./day/year)

N/A

N/A

08/27/2019

N/A

N/A

B. Estimated date tank closed
(mo./day/year)





10/26/2019





C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)





N/A





3. Evidence of a Leak Detected (Y/N)





No





XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F"?T1

Tank No. F"ST2

Tank No. F"ST3

Tank No. F"ST4

Tank No. """"H

A. Date Repaired

N/A

N/A

N/A

07/25/2019

N/A

B. Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)
Tank F-ST4:



Contractor completed a comprehensive out-of-service internal integrity inspection and repair of Surge Tank 4.
Completed shell repairs included various weld and patch plate repairs. Based on inspection of the repairs and
review of documentation of the repairs, the Engineer of Record determined Surge Tank 4 is suitable to return to
service, as specified in the Contractor's Suitability for Service Testament (attached).

Leak detection testing of Surge Tank 4 was performed, with no detectable leak above the test method's minimum
detectable leak rate, resulting in a passing test. The leak detection testing conducted meets the regulatory
requirements in HAR 11-280.1-43(10). The Executive Summary of the 2019 Annual Leak Detection Testing Report
of 17 Bulk Field-Constructed Underground Storage Tanks at Red Hill Fuel Storage Complex is attached.

C. Select one of the following:

i. Installation certified by tank and
piping manufacturers

N/A

N/A

N/A

N/A

N/A

ii. Installation inspected by a
registered engineer.

N/A

N/A

N/A

Yes

N/A

iii. Manufacturer's installation
checklists have been completed
and documented

N/A

N/A

N/A

N/A

N/A

iv. Another method allowed by the
department. Please specify

N/A

N/A

N/A

N/A

N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 27 of 33

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale This drawing should show the following

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified Ov number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. "' P

Tank No. "fl

Tank No """El

Tank No. '"CI

Tank No.

1.

Status of Tank (Mark only one)











A. Currently in Use

0

0

0

0

~

B. Temporarily Out of Use

(Also complete Section XI)

~

~

~

~

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

07/2010

05/2006

09/2011

06/2006



3.

Estimated Capacity (gallons)

2,000

4,000

59,500

236,579





A Compartmentalized? Yes/No

No

No

No

No





Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No



4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A Gasoline (Specify product grade)

N/A

N/A

N/A

N/A



B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A



D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Oate: 7/16/2018 (rev February 1, 2019)

Page 28 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. B

Tank No. D

Tank No.

Tank No. ""H

Tank No.

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A



H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A



1. Other, please specify.

F-24

F-24

F-24

F-24



5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes



6. Tank (Mark all that apply)

A. Manufacturer and Model

Steel Tank
lnstitute/STI-P3

Steel Tank
lnstitute/STI-P3

N/A

N/A



B. Underwriters Laboratory No.

UL-58

UL-58

N/A

N/A



C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

13

13

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

IZ1

13

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A



iv. None

~

~

~

~

~

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

13

13

~

~

~

iii. Impressed current system

13

0

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A



7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown



B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown



Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 29 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. PRT'S

Tank No. PRTfl

Tank No. "TJ

Tank No.

Tank No.

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

13

13

13

0

~

iv. Other, please specify.

N/A

N/A

N/A

N/A



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

13

0

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A



v. None

~

~

13

0

~

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

13

0

0

0

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A



8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

~

~

0

0

~

D. Not Applicable

13

13

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A



B. Capacity (gallons)

N/A

N/A

N/A

N/A



10. Overfill prevention equipment

0

13

~

~

~

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

13

Veeder-Root
TLS-350 PLUS

13

Veeder-Root
TLS-350 PLUS



~

~

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 30 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No."" B

Tank No. W7B

Tank No. 3"B

Tank No.c"B

Tank No.

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

~

NA

~

NA

~

NA

~

NA

~

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

0

~

0

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A

If YES, specify type.











J. Line tightness testing

NA

0

NA

0

NA

0

NA

0

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A





X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 31 of 33

-------
Facility ID No. 9-102271
XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE	

Tank Number

Tank No. '"ta

Tank No. "~ti

Tank No. DJ"n

Tank No,

Tank No.

1. Closing of Tank

A. Estimated date last used
(mo./day/year)

N/A

N/A

N/A

N/A



B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. P"T-Q

Tank No. p"TfJ

Tank No. "13

Tank No. 6""t3

Tank No.

A.

Date Repaired

N/A

N/A

N/A

N/A



B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form No. 1	pa„„ 37 Qf 33

Date: 7/16/20XS (rev February 1, 2019)

-------
Facility ID No. 9-102271

XIII. CERTIFICATION (Read and sign after completing all sections)

I certify under penalty of law that I have personally examined and am familiar with the information submitted in this and all attached
documents, and that based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the
submitted information is true, accurate, and complete.

CAPT Marc Delao

Print or Type Name of owner or owner's authorized repn

Signature

Regional Engineer

Official Title

10





Date Signed

Status of Signatory (Mark as appropriate)

1.	Corporation:

2.	Partnership:

3.	Sole proprietorship:

4.	Government entity:

~principal executive officer

~	duly authorized representative

~	general partner

~	proprietor

~	principal executive officer

~	ranking elected official

Notification for Underground Storage Tanks - form No, 1
Date: 7/16/2018 (rev February 1, 2019)

Page 33 of 33

-------
-------
ENGINEERING, INC.

SUITABILITY FOR SERVICE TESTAMENT
TANK 5

Enterprise Engineering, Inc. (EEI), under contract to APTIM (NAVFAC EXWC Contract No. N39430-
15-D-1632, Task Order N3943019F4021), completed a comprehensive, out-of-service, internal integrity
inspection and suitability for service evaluation of Tank 5 at the Red Hill Fuel Storage Facility, NAVSUP
FLC, Pearl Flarbor, Hawaii. EEI performed an inspection ofTank 5 October 2017 through January 2018
under a separate contract to NAVFAC EXWC (N39430-15-D-I678 Delivery Order 0011). Subsequently,
APTIM completed repairs identified in EEI's Final Condition Assessment Report (Pre-Repair) dated
November 2019 and Government Issued RFP documents dated 07 May 2018.

EEI performed a post-repair inspection ofTank 5 April 2019 through October 2019. The post-repair
inspection determined repairs have been completed in accordance with the repair design documents. This
report provides a status of the repairs performed, Non-Destructive Evaluation performed, a revised DLA-
E Tank Condition Form (Post-Repair), a final repair list with repair location and size and certificates of
EEI personnel who worked in Tank 5. EEI's Final Condition Assessment Report (Pre-Repair) is included
in the appendices for historical information.

EEI recommends the next internal out-of-service inspection be scheduled no later than April 2040 (20
years from the return to service (RFS) date April 2020) or sooner if a change in condition has occurred.

Based on the inspection of the repairs and review of documentation of the repairs, EEI
has determined Tank 5 is suitable to return to service.

POST-REP Am

(b) (4)

Storage Tank Engineer and Inspector of Record
API 653 AST Inspector Certificate No. f~

8 January 2020

Date

Falmouth, ME 04105 • 400 Route 1, North Suite B. 207.869.8006 • Fax 207.859.8015
Anchorage, AK 99503 • 2525 Gambell Street, Suite 200 • 907.563.3835 • Fax 907.553.3817
Honolulu, HI 96819 • 3375 Koapaka Street, Suite B232 • 808.260.1481

^Cl0SURE(z.)

-------
-------
Michael Baker

Project: 176419

ENCLOSURES r*"

2020 LEAK DETECTION TESTING
REPORT OF BULK FIELD-
CONSTRUCTED UNDERGROUND
STORAGE TANK 5 AT RED HILL
FUEL STORAGE COMPLEX

JOINT BASE PEARL HARBOR-
HICKAM, HAWAII

Prepared for:

Defense Logistics Agency Energy
Fort Belvoir, Virginia

Prepared under:

Naval Facilities Engineering Command
Atlantic Contract N62470-16-D-9007
Delivery Order N6247020F4015

Submitted by:

Michael Baker International
Virginia Beach, Virginia

Date:

30 April 2020

-------
EXECUTIVE SUMMARY

The scope of this project is to perform leak detection testing of bulk field-constructed underground storage
tank (BFCUST) 5, at four different product levels, at the Red Hill Fuel Storage Complex at Joint Base (JB)
Pearl Harbor-Hickam, Hawaii. The leak detection testing is being conducted at the direction of the Naval
Facilities Engineering Command (NAVFAC) Atlantic and the Defense Logistics Agency (DLA) Energy's
Leak Detection Centrally Managed Program and meets the regulatoiy requirements stated in the Hawaii
Administrative Rules, Title 11, Chapter 280.1 (HAR 11 -280.1), Subchapter 4, § 11 -280.1 -43( 10).

The leak detection testing of BFCUST 5 was performed, by	between 4

March and 20 April 2020, at four different product levels, with no detectable leak above the test method's
minimum detectable leak rate, resulting in passing tests.

In accordance with HAR 11-280.1, annual leak detection testing of BFCUST 5 must be initiated on or
before 4 March 2021; however, testing should be initiated on or before 16 October 2020 to align with annual
leak detection testing of 22 BFCUSTs.

Environmental regulatory compliance of this site is the responsibility of the base and the service.

-------
ENGINEERING, INC

SUITABILITY FOR SERVICE TESTAMENT
SURGE TANK 4 (FACILITY NO. 1227)

Enterprise Engineering Inc. (EEI), under contract to APTIM under (NAVFAC EXWC Contract No.
N39430-15-D-1632, Task Order 3974318F4132), completed a comprehensive, out-of-service external and
internal integrity inspection and suitability for service evaluation of Surge Tank 4 at NAVSUP FLC Pearl
Harbor, Hawaii. The out-of-service inspection was performed November 13 through November 27,2018.
Subsequently, APTIM completed repairs identified in EEI's Final Condition Assessment Report (Pre-
Repair) dated June 2019.

EEI performed a post-repair inspection of Tank 4 on June 28, 2019. The inspection determined repairs are
complete and in accordance with the repair design documents. This report provides a summary of the
repairs identified in EEI's Final Condition Assessment Report (Pre-Repair), status of repairs, a revised
DLA-E Tank Condition Form (Post-Repair), and the Final Condition Assessment Report (Pre-Repair).

EEI recommends the next internal out-of-service inspection be scheduled no later than November 2028
(10 years after the November 2018 inspection), or sooner if a change in condition has occurred.

Based on the inspection of the repairs and review of the repair documentation
of the repairs, EEI has determined Tank 4 is suitable to return to service.

July 8. 2019

POST-REPAIR



Date

API 653 AST Inspector Certificate No.

(b)(4) |

API 653 AST Inspector Certificate No.

Date

July 8,2019

-------
-------
2019 ANNUAL LEAK DETECTION
TESTING REPORT OF 17 BULK
FIELD-CONSTRUCTED
UNDERGROUND STORAGE
TANKS AT RED HILL FUEL
STORAGE COMPLEX

JOINT BASE PEARL HARBOR-
HICKAM, HAWAII

Prepared for:

Defense Logistics Agency Energy
Fort Belvoir, Virginia

Prepared under:

Naval Facilities Engineering Command
Atlantic Contract N62470-16-D-9007
Delivery Order 0004

Submitted by:

Michael Baker International
Virginia Beach, Virginia

Date:

8 January 2020

Michael Baker

INTERNATIONAL

ENCLOSURESr

Project: 155858
'ask: 3.0

-------
EXECUTIVE SUMMARY

The scope of this project is to perform annual leak detection testing of 22 bulk field-constructed
underground storage tanks (BFCUSTs) at the Red Hill Fuel Storage Complex at Joint Base (JB) Pearl
Harbor-Hickam, Hawaii. The annual leak detection testing is being conducted in accordance with the
Administrative Order on Consent (AOC), signed September 2015, between the Commander Navy Region
Hawaii, Defense Logistics Agency (DLA) Energy, the State of Hawaii Department of Health, and the
United States Environmental Protection Agency Region 9 and meets the regulatory requirements stated in
the Hawaii Administrative Rules, Title 11, Chapter 280.1 (HAR 11-280.1), Subchapter 4, §11-280.1-
43(10).

Upon mobilization and system review, five BFCUSTs (BFCUSTs 5, 13,14, 17, and SI226) were removed
from testing due to being temporarily out-of-service. Consequently, the final 2019 annual leak detection
testing event included 17 BFCUSTs at the Red Hill Fuel Storage Complex at JB Pearl Harbor-Hickam.

The annual leak detection testing of 17 BFCUSTs was performed, by |

between 16 October and 27 November 2019, with no detectable leak above the test method's minimum
detectable leak rate, resulting in passing tests. BFCUSTs 7, 8, 15, 16, 18, and 20 were tested at less than
tank high level, per base request, due to operational issues at the time of testing.

NAVFAC Atlantic and DLA Energy's Leak Detection Centrally Managed Program (CMP) should be
notified immediately when BFCUSTs5, 13, 14, 17, and SI 226 are returned to service and when BFCUSTs
7. 8,15,16. 18, and 20 product levels are returned to normal operating levels to facilitate immediate testing,
to comply with the AOC.

In accordance with the DLA Energy's Leak Detection CMP, as a pollution prevention Best Management
Practice, semi-annual leak detection testing of 18 BFCUSTs should be performed on or before 16 April
2020.

In accordance with the AOC, annual leak detection testing of 22 BFCUSTs at JB Pearl Harbor-Hickam
must be initiated on or before the anniversary date of 16 October 2020. Environmental regulatory
compliance of this site is the responsibility of the base and Naval Supply Systems Command.

-------
DEPARTMENT OF THE NAVY

COMMANDER
NAVY REGION HAWAII
850 TICONDEROG A ST STE 110
JBPHH, HAWAII 96860-5101

SEP 2 4 2020 0 44*-

5000-45A
N45

September 15, 2020

CERTIFIED NO: 7015 0640 0002 4678 0561

Ms. Roxanne Kwan
Hawaii State Department of Health
Solid and Hazardous Waste Branch
Underground Storage Tank Section
2827 Waimano Home Road #100
Pearl City, HI 96782

Dear Ms. Kwan:

SUBJECT: NOTIFICATION FOR UNDERGROUND STORAGE TANKS, RED HILL BULK FUEL
STORAGE FACILITY, JBPHH, OAHU, DOH FACILITY ID NO. 9-102271

As required by Hawaii Administrative Rules 11-280.1-34, the Navy is submitting written notification
for the return to currently-in-use status of Surge Tank 3 (F-ST3) and the temporary closure of Surge Tank
1 (F-ST1). DOH Form No. 1, Notification for Underground Storage Tanks, is being submitted as
Enclosure I.

Enterprise Engineering, Inc. performed a post-repair inspection of Surge Tank 3 and determined repairs
were completed in accordance with repair design documents. A Suitability of Service Testament for
Surge Tank 3 is being submitted as Enclosure 2.

A leak detection test was conducted on Surge Tank 3 with passing results. The tank tightness test
summary is being submitted as Enclosure 3. In accordance with Exemption (b)(4) of the Freedom of
Information Act, the name of the subcontractor who performed the leak detection test has been redacted.

If you have any questions regarding this matter or need any additional information, contact

(b) (6)

(b) (6)

L»irecior

Regional Environmental Department

By direction of the

Commander

-------
5000-45A
N45

September 15, 2020

Enclosures: 1. DOH Form No. 1, Notification for Underground Storage Tanks for Red Hill Bulk Fuel
Storage Facility, JBPHH, Oahu, DOH Facility ID No. 9-102271

2.	Suitability for Service Testament for Surge Tank 3 (Facility No. 1226), prepared by
Enterprise Engineering, Inc., 22 Jul 2020

3.	Tank Tightness Test Summary, 24 Aug 2020 (Redacted)

Copy to:

U.S. Environmental Protection Agency Region 9

Commander, Navy Region Hawaii

Naval Facilities Engineering Command, Hawaii

U.S. Naval Supply Systems Command Fleet Logistics Center Pearl Harbor

2

-------
SOLID AND HAZARDOUS WASTE BRANCH
Underground Storage Tank Program

2827 Waimano Home Road #100 • Pearl City, Hawaii 96782
Phone: 808 - 586- 4226 • Fax: 808-586-7509 • http://www.haMaii.gov/heallh/environinental/waste/ust

NOTIFICATION FOR UNDERGROUND STORAGE TANKS

I

Facility ID Number:
Permit Number:

Return completed form to:

Solid and Hazardous Waste Branch
Underground Storage Tank Program
2827 Waimano Home Road #100
Pearl City, Hawaii 96782

9-102271

Type of Notification/s: (Check all that apply)

0UST Status Change (temporary or permanent closure or return to use)
CDchange in Piping

LUchange in Spill and/or Overfill Prevention Method
Dchange in Release Detection Method
djchange in Financial Responsibility Mechanism

dlother:	

Date Activity Occurred: _

09/13/2020 (F-ST1), 08/17/2020 (F-ST3)

State Use Only

Date received:		

Date Entered into Computer:	

Data Clerk's Initials:		

Comments:

I. LOCATION OF TANK(S)

Red Hill Bulk Fuel Storage Facility

Facility Name or Company Site identifiers

Location Contact Person

Red Hill

Aiea

Location Address (P.O. Box not acceptable)

City

96701 Oahu

Hawaii

State Zip Code

Island

990-0006. >9010001 11012003 11012004

Tax Map Key#

(808)473-7801

Location Phone # (w/ area code)

(808)473-7815

Location Fax # (w/ area code)

Phone # (w/ area code)

II. CONTACT PERSON IN CHARGE OF TANK(S)

Regional Fuels Officer

Fax # (w/ area code)

Name





Job / Position Title



1942 Gaftney Street.



JBPHH

HI

96860

Mailing Address



City

State

Zip Code



(808)473-7815







E-mail Address

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 1 of 33

ENCLOSURE!/)

-------
Facility ID No. 9-102271

III. OWNER OF TANK(S)

US Navy - COMNAVREG HI

Owner Name (Corporation, Individual, Public Agency, or Other Entity)







850 Ticonderoga Street, Suite 110 JBPHH



HI

96860

Mailing Address City



State

Zip Code

(808)471-3926 (808)473-5024

james.meyer@navy.mil



Phone # (w/ area code) Fax # (w/ area code)



E-mail Address



IV. OPERATOR OF TANK(S) (if same as Section III, check here

Naval Supply Systems Command Fleet Logistics Center Pearl Harbor

H>



Operator Name (Corporation, Individual, Public Agency, or Other Entity)

1942 Gaffney Street, JBPHH



HI

96860

Mailing Address City



State

Zip Code

(808)473-7815





I

Phone # (w/ area code) Fax # (w/ area code)



E-mail Address



V. TYPE OF FACILITY (Select the appropriate facility description)

EH Airline

EHcontractor

EH Petroleum Distributor

I I Service Centers/Auto Repair/Maintenance

EH Auto Dealership

I iFarm

EH Police Station

I IT ruckingH" ransporter

EH Baseyard

EH Fire Station

EH Residential

I I Utilities

EH Car Rental

EHGas Station

EH Resort/Hotel

I I Wastewater Treatment Plants

EH Cleaner/Laundromat

EHcolf Course

EH School

EH Wholesaler/Retailer

EH Communication Sites

EH Hospital

[7] Other (Explain) Fuel Storage and Airfield Hydrant System

VI. FINANCIAL RESPONSIBILITY (Check all that apply)

~	Commercial Insurance

~	Financial Test of Self Insurance
EH Guarantee

~ Letter of Credit
EH Surety Bond
EH Trust Fund

~ Local Government Bond Rating Test

I I Other Method Allowed (Specify)	

[3 Exempt: EH State or Federal Agency

Checking one or more of the above boxes attests to the fact that the financial responsibility requirements in subchapter 8 of chapter
11-280.1, Hawaii Administrative Rules, are met using the selected mechanism(s) as of the date of the certification below.

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 2 of 33

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A	The property boundaries of the facility;

B	Identification of streets, roads and nearby bodies of water;

C	Identification of nearby facilities;

D	Tax Map Key (TMK) Numbers;

E	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in

Sections IX and X), and associated pipings; and

H	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No F"1

Tank No F"2

Tank No ^-3

Tank No F-4

Tank No f"-5

1.

Status of Tank (Mark only one)











A Currently in Use

~

0

0

I 0

0

B. Temporarily Out of Use
(Also complete Section XI)

0

~

~

~

~

C. Permanently Out of Use
(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

10/1942

09/1942

01/1943

11/1942

12/1942

3.

Estimated Capacity (gallons)

12,000,000

12.000,000

12,000,000

12,000,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)











B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D Kerosene

~

~

~

~

~

Notification for underground Storage Tanks - Form No 1
Date: 7/16/2018 (rev February 1, 2019)

Page 3 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. ^-1

Tank No. F-2

Tank No. F-3

Tank No. F-4

Tank No. F'5

E. Used Oil/Waste Oil



~





c





c



~



c



F. JP-4

~

~



c





c





~



G, Non-Petro!eum Hazardous Substance
(CERCLA name and/or CAS #}

N/A

N/A

N/A

N/A

N/A

H, Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

EMPTY

F-24

F-24

F-24

F-24

5. Substance Compatible with
Tank and Piping? Yes/No



Yes

Yes

Yes

Yes

6. Tank {Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic



c





c





c





c





~



ii. Steel



E





E





E





E





E



iii, Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced piastic



C





~





~





~





~



ii. Steel



c





~





~





~





~



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None



[Z





0





0





E





E



E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

I

~





~



I

~





~



I

~



ii. Double-walled steel

I

~





~



I

~





~



[

~



iii. Impressed current system

I

~





~



I

~





~



I

~



iv. Sacrificial anode system

I

~





~



I

~





~



I

~



v. Corrosion expert determination

I

~



]

~



I

~





~



I

~



vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B, Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 4 of33

-------
Facility ID No. 9-102271

Tank Number

Tank No. ^

Tank No. ^-2

Tank No. ^

Tank No. F"4

Tank No. ^-5

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steei

13

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~



C



~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

0

0

0

0

0

E, Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B, Safe Suction (no valve at tank)

~

~

~

~

~

C, Pressure

13

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~ I

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

0

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~



~



~

~

B. Overfill alarm
Make and Model

0

0



~



0

0

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No, 1
Date: 7/16/2018 (rev February 1, 2019)

Page 5 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"1

Tank No. F"2

Tank No. F"3

Tank No. F"4

Tank No. F*5

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B Tank tightness testing

~

NA

13

NA

0

NA

13

NA

13

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No 1
Date: 7/16/2018 (rev February 1, 2019)

Page 6 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE	

Tank Number

Tank No. F-1

Tank No. F-2

Tank No. F-3

Tank No. F-4

Tank No. F-5

1 Closing of Tank

A. Estimated date last used
(mo./day/year)











8, Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F-1

Tank No. F"2

Tank No. F"3

Tank No. F"4

Tank No.

A.

Date Repaired

N/A

N/A

N/A

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary,)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form No. 1	pa„e 7 0f 33

Date: 7/16/201S (rev February X, 2019)

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A	The property boundaries of the facility;

B	Identification of streets, roads and nearby bodies of water;

C	Identification of nearby facilities;

D	Tax Map Key (TMK) Numbers;

E	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in

Sections IX and X), and associated pipings; and

H	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F-6

Tank No. F"7

Tank No. F"8

Tank No F-9

Tank No. F_1°

1.

Status of Tank (Mark only one)











A Currently in Use

0

0

0

0

0

B Temporarily Out of Use
(Also complete Section XI)

~

~

~

~

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

12/1942

05/1943

03/1943

02/1943

01/1943

3.

Estimated Capacity (gallons)

12,700,000

12.700,000

12,700,000

12,700,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A Gasoline (Specify product grade)











B Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 8 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F'6

Tank No

F-7

Tank No. ^-8

Tank No

F-9

Tank No. F"1Q

E. Used Oil/Waste Oil



c





c





c





II





II



F. JP-4



L





c





c





C





II



G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances {Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-24

JP-5

JP-5

JP-5

JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C, Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic



~





~





~





c





~



ii Steel



E





E





E





E





E



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

!. Fiberglass reinforced plastic



~





~





~





~





~



ii. Steel



~





~





~





~





~



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None



0





0





E





B





E



E, Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

1

~



1

~



1

~





~



I

~



ii. Double-walled steel

I

~

1

~



1

~



I

~



I

~



iii. Impressed current system

1

~



1

~



I

~



1

~



I

~



iv. Sacrificial anode system

I

~



1

~



I

~



1

~



I

~



v, Corrosion expert determination

1

~



1

~



1

~



1

~



I

~



vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No, 1
Date: February 1, 2019

Page 9 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"6

Tank No. F_7

Tank No.

Tank No,

Tank No. F"10

C, Primary Containment Material or Single-Waited Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

0

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

[3

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

0

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

0

0

0

0

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 10 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F-6

Tank No. F-7

Tank No. F-8

Tank No. F-9

Tank No.F"10

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

0

NA

B Tank tightness testing

0

NA

0

NA

0

NA

0

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

0

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

0

NA

E. Vapor monitoring

~

~

~

~

~

~

o

~

0

O

F. Groundwater monitoring

~

~

~

~

~

~

o

0

O

0

G Interstitial monitoring

~

~

~

~

~

~

o

0

o

o

H. Statistical inventory reconciliation

~

~

~

~

~

~

o

0

0

0

I Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

0

NA

O

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

NA

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks • Form No 1
Date: 7/16/2018 (rev February 1,2019)

Page 11 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE	

Tank Number

Tank No, F-6

Tank No. F-7

Tank No, F-8

Tank No. F-9

Tank No. F"10

1. Closing of Tank

A. Estimated date last used
(mo./day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F-6

Tank No.

Tank No. ^-8

Tank No. F"9

Tank No. F~10

A,

Date Repaired

N/A

N/A

N/A

N/A

N/A

B

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. installation certified by tank and
piping manufacturers











it. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form Mo. 1	p,„p ,1.1,;

Date; 7/16/2018 (rev February 1, 2019)	B

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundanes of the facility;

B.	Identification of streets, roads and nearby bodies of water,

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X). and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F"11

Tank No. F"12

Tank No. F"1j

Tank No. F'14

Tank No. F"15

1.

Status of Tank (Mark only one)











A. Currently in Use

0

0

~

~

0

B. Temporarily Out of Use

(Also complete Section XI)

~

~

0

0

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

02/1943

03/1943

03/1943

03/1943

04/1943

3.

Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A Gasoline (Specify product grade)











B Diesel

~

~

~

~

~

C, Gasohol (Including ethanol blends)
Specify product grade











D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February t, 2019)

Page IB of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No ! 1

Tank No. F'12

Tank No. F'13

Tank No. p-14

Tank No. F"15

E, Used Oil/Waste Oil



c





~





c





c





C



F. JP-4



c





c





c





c





c



G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify}

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

JP-5

JP-5

EMPTY

EMPTY

F-76

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes





Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic



c





C





~





~





c



ii. Steel



[Z





IZ





e





E





E



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D, Secondary Containment Material

i. Fiberglass reinforced plastic



c





~





~





~





~



ii. Steel



~





~





~





~





~



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None



E





0





E





3





3



E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

[

~





~



I

~



I

~



[

~



ii. Double-walled steel

I

~



I

~



I

~



I

~



I

~



iii. Impressed current system

[

~



I

~



I

~



I

~



I

~



iv. Sacrificial anode system

1

~



I

~



I

~



I

~



I

~



v. Corrosion expert determination

1

~



[

~



I

~



I

~



(

~



vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1,2019

Page 14 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F~11

Tank No. F"12

Tank No. F"13

Tank No. F"14

Tank No. F"15

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

0

Hi. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

0

ii. Flex piping

~

~

~

~

0

iii. Lined trench

~

~

~

~

0

iv. Other, please specify.











v. None

0

0

0

0

0

E Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

0

ii. Impressed current system

~

~

~

~

0

iii. Sacrificial anode system

~

~

~

~

o

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

0

B. Safe Suction (no valve at tank)

~

~

~

~

O

C. Pressure

0

0

0

0

0

D. Not Applicable

~

~

~

~

0

9. Spill prevention equipment

~

~

~

~

0

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10, Overfill prevention equipment

0

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

0

B, Overfill alarm
Make and Model

0

0

~

0

0

C Ball float valve
Make and Model

~

~

~

0

o

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2013 (rev February 1, 2019)

Page 15 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. r"11

Tank No.F'12

Tank No. F"13

Tank No.F"14

Tank No. F"15

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B Tank tightness testing

0

NA

0

NA

0

NA

0

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No 1
Date: 7/16/2018 (rev February 1, 2019)

Page 16 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE	

Tank Number

Tank No, F"11

Tank No. F*12

Tank No. F"13

Tank No. F"14

Tank No. F"15

1. Closing of Tank

A. Estimated date fast used
(mo./day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F"11

Tank No. F"12

Tank No. F"13

Tank No. F~14

Tank No. F~15

A.

Date Repaired

N/A

N/A

N/A

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. PI ease specify











Notification for Underground Storage Tanks - Form No. 1	, 7 nf 33

Date: 7/16/2018 [rev February 1, 2019)	6

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility,

B.	Identification of streets, roads and nearby bodies of water,

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F"16

Tank No. F~17

Tank No. F'18

Tank No. F"19

Tank No. F"20

1.

Status of Tank (Mark only one)











A. Currently in Use

0

~

~

~

P 0

B. Temporarily Out of Use

(Also complete Section XI)

~

0

0

0

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

05/1943

05/1943

05/1943

06/1943

07/1943

3.

Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)











B Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D Kerosene

~

~

~

~ I

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev rebruary 1, 2019)

Page 18 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"1S

Tank No. F"17

Tank No. F'1S

Tank Nc

F-19

Tank No. F~20

E. Used Oil Waste Oil



c





C





c





C



~

F. JP-4

~

~



c





C





c



G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-76

EMPTY

EMPTY

EMPTY

JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes







Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-

constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic



c





c



~

~



c



ii. Steel



[Z





E



0

0



E



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic



~





~





~





~



~

ii. Steel



C





~





~



~



~



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None



E





0





0





3





E



E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

I

~





~



I

~



~

~

ii. Double-walled steel

I

~



~



~

~



~



iii. impressed current system

~

I

~



I

~



I

~



I

~



iv. Sacrificial anode system

[

~



~

(

~



I

~



I

~



v. Corrosion expert determination

I

~



I

~



~

I

~



I

~



vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 19 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F~16

Tank No. F"17

Tank No. F'18

Tank No. F"19

Tank No. F"20

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic



3





3





3





3



~

ii. Flex piping



3





3





3





3





3



iii. Steel



E





[Z





E





E





E



iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic



~





3





3





3

I



3



ii Flex piping



~





3





II





~





3



iii. Lined trench



~





~





II





3





3



iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

13



E





E





E





E



E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel



~





~





~





~





3



ii. Impressed current system



~





~





3





3





3



iii. Sacrificial anode system



~





~





3





3





3



iv. Corrosion expert determination



~





~





3





3





3



v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)



~





3





3





3



I

3



B. Safe Suction (no valve at tank)



~





3





3





3



I

3



C. Pressure



3





3





3



I

3



I

3



D. Not Applicable



~





3





3



I

3



I

3



9. Spill prevention equipment



~



I

3





3



I

3



I

3



A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment



3



0

I

3





3





E



A. Automatic shutoff device (flapper)
Make and Model



~



I

3



I

3





3





3



B, Overfill alarm
Make and Model



3





3





/



I

3





E



C. Ball float valve
Make and Model

""1

3





3





3



I

3





3



Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 20 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F-1G

Tank No.r"17

Tank No. r"18

Tank No. p~19

Tank No. F"20

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B Tank tightness testing

0

NA

0

NA

13

NA

~

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No 1
Date: 7/16/2018 (rev February 1, 2019)

Page 21 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE

Tank Number

Tank No F"16

Tank No. F-17

Tank No. F~18

Tank No. F_19

Tank No. F"20

1. Closing of Tank

A. Estimated date last used
(mo. /day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was dosed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. SiteAssessmentCompleted (Y/N)





No





3. Evidence of a Leak Detected (Y/N)





No





XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F"16

Tank No. F"17

Tank No. F_1S

Tank No. F"19

Tank No. F-2°

A

Date Repaired

N/A

N/A

N/A

N/A

N/A

B

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 [rev February 1, 2019)

Page 22 of 33

-------
Facility IDNo. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following

A	The property boundaries of the facility;

B	Identification of streets, roads and nearby bodies of water,

C.	Identification of nearby facilities;

D	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in

Sections IX and X), and associated pipings; and

H	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F-ST1

Tank No. F'sr?

Tank No. F'ST3

Tank No. frsT4

Tank No. '"'O

1.

Status of Tank (Mark only one)











A. Currently in Use

~

0

0

0

0

B Temporarily Out of Use

(Also complete Section XI)

0

~

~

~

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

07/1942

07/1942

07/1942

07/1942



3.

Estimated Capacity (gallons)

400,000

400;000

400,000

400,000

31,665



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A Gasoline (Specify product grade)











B Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 2 3 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F'5T1

Tank No.F ST2

Tank No. F ST3i

Tank No.IfH

Tank No. *na

E, Used Oil/Waste Oil



C





C





c





c





c



F. JP-4



c





~





c





~





II



G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

[, Other, please specify.

EMPTY

JP-5

F-24

F-76

F-24, F-76, JP-5

5. Substance Compatible with
Tank and Piping? Yes/No



Yes

Yes

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-

constructed

N/A

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic



c





c





~





c





C



ii. Steel



E





E





E





E





~



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic



~





~





~





~





~



ii. Steel



c





~





~





~





~



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None



E





a





E





B





~



E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

I

~



I

~



[

~





~



I

~



ii. Double-wailed steel

I

~



I

~



I

~



I

~



I

~



iii. Impressed currentsystem

I

~



I

~



I

~



I

~



I

~



iv. Sacrificial anode system

I

~



I

~



[

~



I

~



[

~



v. Corrosion expert determination

I

~



I

~



[

~



I

~



[

~



vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 24 of 33

-------
Facility iDNo. 9-102271

Tank Number

Tank No. F~ST1

Tank No.F ST2

Tank No.F-ST3

Tank No. F'ST4

Tank No. °"'H

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping rs above ground

Piping is above ground

Piping is above ground



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, piease specify.

N/A

N/A

N/A

N/A

N/A

v. None

0

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~



~



~

~

~

ii. Impressed current system

~

~

~

~

0

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

~

~

~

~

0

D. Not Applicable

0

0

0

0

~

9. Spill prevention equipment

~



~



~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

[3

0

0

0

~

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

0

~

0

~

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 25 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F'ST1

Tank No. e"ST2

Tank No. F-ST3

Tank No. F*ST4

Tank No.

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

0

NA

0

NA

0

NA

0

NA

~

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES. specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

0

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 26 of 33

-------
Facility ID No. 9-102271

XL TANK(S) OUT OF USE OR CHANGE IN SERVICE

Tank Number

Tank No. F ST1

Tank No. F_ST2

Tank No. FSTS

Tank No. F~ST4

Tank No.

1. Closing of Tank

A. Estimated date last used
(mo./day/year)

07/15/2020









B Estimated date tank ctosed
(mo./day/year)

09/13/2020









C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)

No









3. Evidence of a Leak Detected (Y/N)

No









XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No F ST1

Tank No. F ST2

Tank No. F ST3

Tank No. F_ST4

Tank No.

A.

Date Repaired

N/A

N/A

08/17/2020

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)





Tank F-ST3:













Contractor completed a comprehensive out-of-service integrity inspection and repair of Surge Tank 3, Completed internal
repairs included new steel floor, one shell patch plate and new stilling well and drain line. Installation of new steel floor
included geotextile fabric, flexible membrane liner, and concrete infill, which was slotted to create a leak detection system.
Based on inspection of the repairs and review of documentation of the repairs, the Engineer of Record determined Surge
Tank 3 is suitable to return to service, as specified in the Contractor's Suitability for Service Testament (attached).

Leak detection testing of Surge Tank 3 was performed, with no detectable leak above test method's minimum detectable
leak rate, resulting in a passing test. The leak detection testing conducted meets the regulatory requirements in HAR
11-280.1-43(10). The Executive Summary of the 2020 Annual Leak Detection Testing Report of Bulk Field-Constructed
Surge Tank 3 is attached.

C

Select one of the following:

i. Installation certified by tank and
piping manufacturers

N/A

N/A

N/A

N/A

N/A

ii. Installation inspected by a
registered engineer.

N/A

N/A

Yes

N/A

N/A

iii. Manufacturer's installation
checklists have been completed
and documented

N/A

N/A

N/A

N/A

N/A

iv. Another method allowed by the
department. Please specify

N/A

N/A

N/A

N/A

N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 27 of 33

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A	The property boundaries of the facility;

B	Identification of streets, roads and nearby bodies of water;

C	Identification of nearby facilities;

D	Tax Map Key (TMK) Numbers,

E	Location of buildings at the facility,

F.	The approximate dimensions of the property boundaries and major buildings;

G	Location of all USTs and dispenser pumps (identified by number/s consistent with the tank & dispenser pump numbers in

Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. ""P

Tank No. m

Tank No.

Tank No JUa

Tank No.

1.

Status of Tank (Mark only one)











A Currently in Use

0

0

0

0

~

B Temporarily Out of Use

(AJso complete Section XI)

~

~

~

~

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2

Date of Installation (mo/year)

07/2010

05/2006

09/2011

06/2006



3.

Estimated Capacity (gallons)

2,000

4,000

59,500

236,579





A Compartmentalized? Yes/No

No

No

No

No





Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No



4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)











B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 28 of 33

-------
Facility ID No, 9-102271

Tank Number

Tank No. PRT fl

Tank No. ™7fS

Tank No. H

Tank No. "B

Tank No.

E. Used Oil/Waste Oil



C





c





c



~

~

F. JP-4

~



~





~





c





L



G, Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A



H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A



1 Other, please specify.

F-24

F-24

F-24

F-24



5, Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes



6. Tank (Mark all that apply)

A. Manufacturer and Mode!

Steel Tank
lnstitute/STI-P3

Steel Tank
lnstitute/ST!-P3

N/A

N/A



B. Underwriters Laboratory No,

UL-58

UL-58

N/A

N/A



C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic



c



~

~

~



c



ii. Steel



E



0

~

~



c



iii. Other, please specify.

N/A

N/A

N/A

N/A



D. Secondary Containment Material

i. Fiberglass reinforced plastic



C





~





~





c



~

ii. Steel



E





3



~

~



~



iii. Other, please specify.

N/A

N/A

N/A

N/A



iv. None



~





~





~





~



~

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

1

~



[

~



~

~

~

it. Double-walled steel

1

3



0

~

~

1

~



iii. Impressed current system

0

1

3



[

~





~



1

~



iv. Sacrificial anode system

~

~

[

~





~



1

~



v. Corrosion expert determination

[

~



~

~

1

~



1

~



vi. Other, please specify.

N/A

N/A

N/A

N/A



7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown



B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown



Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 29 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No.

Tank No. " 0

Tank No.

Tank No. E""D

Tank No.

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

O

O

ii. Flex piping

~

~

~

0

O

iii. Steel

0

0

0

0

0

iv. Other, please specify.

N/A

N/A

N/A

N/A



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

0

0

ii. Flex piping

~

~

~

0

o

iii. Lined trench

0

0

0

0

0

iv. Other, please specify.

N/A

N/A

N/A

N/A



v. None

~

~

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

0

~

0

ii. Impressed current system

0

0

0

0

0

iii. Sacrificial anode system

~

~

0

0

0

iv. Corrosion expert determination

~

~

0

O

0

v. Other, please specify.

N/A

N/A

N/A

N/A



8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

0

0

0

B. Safe Suction (no valve at tank)

~

~

O

O

o

C. Pressure

~

~

0

0

0

D. Not Applicable

13

0

0

0

o

9. Spill prevention equipment

~

~

o

0

o

A. Manufacturer and Model

N/A

N/A

N/A

N/A



B. Capacity (gallons)

N/A

N/A

N/A

N/A



10. Overfill prevention equipment

0

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

0

0

0

B. Overfill alarm
Make and Model

0

Veeder-Root
TLS-350 PLUS

0

Veectef-Root
TLS-350 PLUS



0

o

C. Ball float valve
Make and Model

~

~

O

0

0

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 30 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No.B

Tank No.PRTn

Tank No. PH3

Tank No. E»»a

Tank No.

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

o

NA

B. Tank tightness testing

~

NA

~

NA

~

NA

~

NA

o

NA

C. Inventory control

~

NA

~

NA

~

NA

0

NA

0

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

0

NA

0

NA

E. Vapor monitoring

~

~

~

~

~

~

o

0

o

0

F. Groundwater monitoring

~

~

~

~

~

~

0

0

0

O

G. Interstitial monitoring

0

~

0

~

~

~

0

O

0

O

H Statistical inventory reconciliation

~

~

~

~

~

~

o

0

o

0

I. Automatic line leak detectors (Yes/No)
If YES, specify type

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J Line tightness testing

NA

0

NA

0

NA

0

NA

0

NA

O

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A





X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 31 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE

Tank Number

Tank No. ZJl

Tank No. PRTfl

Tank No. :'"~n

Tank No.

Tank No.

1. Closing of Tank

A. Estimated date last used
(mo./day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. ""'fl

Tank No. "ra

Tank No.

Tank No.

Tank No.

A.

Date Repaired

N/A

N/A

N/A

N/A



B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 32 of 33

-------
Facility ID No. 9-102271

XIII. CERTIFICATION (Read and sign after completing all sections)

I certify under penalty of law that I have personally examined and am familiar with the information submitted in this and all attached
documents, and that based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the
submitted information is true, accurate, and complete.

(b) (6)

Print or Tyl

Signature

(b) (6)

ed representative

Regional Environmental Program Director
Official Title

Date Signed

Status of Signatory (Mark as appropriate)

1.	Corporation:

2.	Partnership:
3 Sole proprietorship:
4. Government entity:

~	principal executive officer

~	duly authorized representative

~	general partner

~	proprietor

~	principal executive officer

~	ranking elected official

Notification for Underground Storage Tanks - Form No 1
Date: 7/16/20X8 (re* February 1, 2019)

Page 33 of 33

-------
ENGINEERING, INC.

SUITABILITY FOR SERVICE TESTAMENT
SURGE TANK 3 (FACILITY NO. 1226)

Enterprise Engineering Inc. (EEI), under contract to APTIM (NAVFAC EXWC Contract No. N39430-
15-D-l632, Task Order 3974318F4132), completed a comprehensive, out-of-service external and internal
integrity inspection and suitability for service evaluation of Surge Tank 3 at NAVSUP FLC Pearl Harbor,
Hawaii. The out-of-service inspection was performed September 25 through October 3, 2019.
Subsequently, APTIM completed repairs identified in the Statement of Work and EEI's Final Condition
Assessment Report (Pre-Repair) dated December 2019.

EEI performed a post-repair inspection of Tank 3 on June 23, 2020. The inspection determined repairs are
complete and in accordance with the repair design documents. This report provides a summary of the
repairs identified in EEI's Final Condition Assessment Report (Pre-Repair), the status of repairs, a revised
DLA-E Tank Condition Form (Post-Repair), and the Final Condition Assessment Report (Pre-Repair).

EEI recommends the next internal out-of-service inspection be scheduled no later than June 2030 (10
years after the June 2020 inspection), or sooner if a change in condition has occurred.

Based or the inspection of the repairs and review of the repair documentation,
EEI has determined Tank 3 is suitable to return to service



POST-REPAIR

July 22, 2020

(b) (4)

| P.E.

API 653 AST Inspector Certificate No.

Date

(b) (4)

July 21,2020

(b) (4)

API 653 AST Inspector Certificate No.

Date

lNCLOSUREU)

-------
APTIM | Government Services
12005 Ford Road; Suite 600
Dallas, TX 75234

FISC Red Hill
Pearl Harbor, HI

Scope of Work: Furnish all required management, labor, services, materials and equipment
to perform the required annual tightness testing of Tank S1226 (Surge 3) an
underground fuel storage tank located at FISC Red Hill, Pearl Harbor, HI.

Summary

Testing of Tank S1226 (Surge 3) a 420,000 gal underground storage tank located at FISC Red Hill,
Pearl Harbor, Hawaii commenced August 11, 2020 and was completed August 14, 2020. The result
of that testing is that the tank system is determined to be tight to isolation. Testing was performed
using the	protocols set out in the third party evaluations. All tank

valves were adequately secured such that any fluid loss was isolated to leakage. Therefore, the
containment integrity of the tank was not compromised and the test is considered conclusive.

Tank S1226 (Surge 3): After 72 hours of testing the tank is certified to be tight.

^CL0SURE(3)

-------
5000-45A
N45

July 16, 2021

Enclosures: 1. DOHFormNo. 1, Notification for Underground Storage Tanks for Red Hill
Bulk Fuel Storage Facility, JBPHH, Oahu, DOH Facility ID No. 9-102271

2.	Suitability for Service Testament for Surge Tank 1 (Facility No. 1224), prepared
by Enterprise Engineering, Inc., April 28, 2021

3.	Tank Tightness Test Summary, June 19, 2021 (Redacted)

Copy to:

U.S. Environmental Protection Agency Region 9

Commander, Navy Region Hawaii

Naval Facilities Engineering Systems Command, Hawaii

U.S. Naval Supply Systems Command Fleet Logistics Center Pearl Harbor

2

-------
JUL 2 2 2

SOLID AND HAZARDOUS WASTE BRANCH
Underground Storage Tank Program

2827 Waimano Home Road #100 • Pearl City, Hawaii 96782
Phone: 808 - 586- 4226 • Fax: 808-586-7509 • http:/Avww.hawaii.gov/health/environmental/waste/ust



NOTIFICATION FOR UNDERGROUND STORAGE TANKS

Facility ID Number:
Permit Number:

Return completed form to:

Solid and Hazardous Waste Branch
Underground Storage Tank Program
2827 Waimano Home Road #100
Pearl City, Hawaii 96782

9-102271

Type of Notification/s: (Check all that apply)

0UST Status Change (temporary or permanent closure or return to use)
CUchange in Piping

^Change in Spill and/or Overfill Prevention Method
CUchange in Release Detection Method
CUchange in Financial Responsibility Mechanism

EHother:	

Date Activity Occurred:	

06/19/2021 (F-ST1)

State Use Only

Date received:		

Date Entered into Computer:	

Data Clerk's Initials:		

Comments:	

I. LOCATION OF TANK(S)

Red Hill Bulk Fuel Storage Facility

Facility Name or Company Site identifiers

Location Contact Person

Red Hill

Aiea

Location Address (P.O Box not acceptable)

96701 Oahu

City

Hawaii

State Zip Code

Island

990I0006. 99010(01. 11312003 11017004

Tax Map Key #

(808)473-7801

Location Phone # (w/ area code)

(808)473-7815

Location Fax # (w/ area code)

(b) (6)

II. CONTACT PERSON IN CHARGE OF TANK(S)

Deputy Fuels Director

Name





Job / Position Title



1942 (iattney Street



JBPHH

HI

96860

Mailing Address



City

State

Zip Code

b> (6)

(808)473-7815





I

Phone # (w/ area code)

Fax # (w/ area code)



E-mail Address



Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 1 of 33

ENCLOSURES )

-------
Facility ID No. 9-102271

III. OWNER OF TANK(S)

US Navy - COMNAVREG HI

Owner Name (Corporation, Individual, Public Agency, or Other Entity)





850 Ticonderoga Street, Suite 110 JBPHH

HI

96860

Mailing Address City

State

Zip Code

(808)471-3926 (808)473-5024

james.meyer@navy.mil



Phone # (w/ area code) Fax # (w/ area code)

E-mail Address



IV. OPERATOR OF TANK(S) (if same as Section I

Naval Supply Systems Command Fleet Logistics Center Pearl Harbor

II, check here |	| )



Operator Name (Corporation, Individual, Public Agency, or Other Entity)

1942 Gaffney Street, HI JBPHH

HI

96860

Mailing Address City

State

Zip Code

(808)4/3-/815





Phone # (w/ area code) Fax # (w/ area code)

E-mail Address



V. TYPE OF FACILITY (Select the appropriate facility description)

EH Airline

EH Contractor

EH Petroleum Distributor

EH Service Centers/Auto Repair/Maintenance

EH Auto Dealership

I iFarm

EH Police Station

I I Trucking/Transporter

EH Baseyard

LHFire Station

EH Residential

I I Utilities

EH Car Rental

EDGas Station

EH Resort/Hotel

I I Wastewater Treatment Plants

EH Cleaner/Laundromat

EHcolf Course

EHschool

EH Wholesaler/Retailer

EH Communication Sites

EH Hospital

0Other (ExDlain) Fuel Storage and Airfield Hydrant System

VI. FINANCIAL RESPONSIBILITY (Check all that apply)

ED Commercial Insurance EHLetter of Credit I I Local Government Bond Rating Test
CD Financial Test of Self Insurance EHsurety Bond	EHOther Method Allowed (Specify)	

CD Guarantee	EHTrustFund	0Exempt: EHstateor [Zl Federal Agency

Checking one or more of the above boxes attests to the fact that the financial responsibility requirements in subchapter 8 of chapter
11-280.1, Hawaii Administrative Rules, are met using the selected mechanism(s) as of the date of the certification below

Notification for Underground Storage Tanks - Form No 1
Date: 7/16/2018 (rev February 1, 2019)

Page 2 of 33

-------
Facility ID No. Q'™2271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F"1

Tank No. F*2

Tank No.

Tank No. F"4

Tank No.

1.

Status of Tank (Mark only one)











A. Currently in Use

~

0

0

0

0

B. Temporarily Out of Use
(Also complete Section XI)

0

~

~

~

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

10/1942

09/1942

01/1943

11/1942

12/1942

3.

Estimated Capacity (gallons)

12,000,000

12,000,000

12,000,000

12,000,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)













B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)











B Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 3 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. ^-1

Tank No. F"2

Tank No. F-3

Tank No. F"4

Tank No.

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

EMPTY

F-24

F-24

F-24

F-24

5. Substance Compatible with
Tank and Piping? Yes/No



Yes

Yes

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

0

0

0

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

0

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 4 of 33

-------
Facility ID No. 9-102271

-

Tank Number

Tank No. F'1

Tank No. ^-2

Tank No. F-3

Tank Nc



Tank No.

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~



c





C





L





~



iii. Steel



E





IZ





E





E





E



iv. Other, please specify.

Piping is above ground

Piping is above ground

Pipsng is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic



~





c



~



C





C



ii. Flex piping



C





c



~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None



E





E





E





E





E



E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system



~





~





~





~





~



iii. Sacrificial anode system



~





~





~





~





~



iv. Corrosion expert determination



~





~





~





~





~



v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8 Method of Product Dispensing

A. Unsafe Suction (valve at tank)



~





~





~





~



1

~



B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

0

0



2



El

El

D. Not Applicable



~



I

~



I

~



1

~



1

~



9. Spill prevention equipment



~



I

~



I

~



1

~



~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment



3



(

a



0

El



E



A. Automatic shutoff device (flapper)
Make and Model



~



[

~



I

~



~

~

B. Overfill alarm
Make and Model

I

2



I

2



~

1

2





E



C. Ball float valve
Make and Model

I

~



I

~





~



1

~





~



Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 5 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F-1

Tank No. F-2

_

Tank No. F-3

Tank No. F"4

Tank No. F-5

11. Release Detection (Mark ail that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

~

NA

El

NA

0

NA

0

NA

H

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks- Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 6 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE

Tank Number

Tank No. F-1

Tank No. F-2

Tank No. F-3

Tank No. F-4

Tank No. F-5

1. Closing of Tank

A. Estimated date last used
(mo./day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F-1

Tank No. F-2

Tank No. F-3

Tank No. F-4

Tank No. F-5

A.

Date Repaired

N/A

N/A

N/A

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 7 of 33

-------
Facility ID No. 9-102271

VIL FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified by number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. ^-6

Tank No. ^-7

Tank No. ^-8

Tank No. ^-9

Tank No. M0

1.

Status of Tank (Mark only one)











A. Currently in Use

0

0

0

0

0

B Temporarily Out of Use
(Also complete Section XI)

~

~

~

~

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

12/1942

05/1943

03/1943

02/1943

01/1943

3

Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)











B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 8 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. ^-6

Tank No. F"7

Tank No. F-8

Tank No. F"9

Tank No. F"10

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-24

JP-5

JP-5

JP-5

JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

12

13

13

0

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

n

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

13

El

[3

13

[3

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 9 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. ^-6

Tank No. ^-7

Tank No. ^-8

Tank No.

Tank No. F"10

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

n

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

0

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

0

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

0

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

[3

0

0

0

0

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 10 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"6

Tank No. F-7

Tank No. F-8

Tank No. F'9

Tank No. F"10

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

0

NA

0

NA

0

NA

0

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

n

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

NA

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. i
Date: 7/16/2018 (rev February 1, 2019)

Page 11 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE	

Tank Number

Tank No. F-6

Tank No. F-7

Tank No. F-8

Tank No. F-9

Tank No. F-10

1. Closing of Tank

A. Estimated date last used
(mo./day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F-6

Tank No. F-7

Tank No. F-8

Tank No. F-9

Tank No. F"10

A.

Date Repaired

N/A

N/A

N/A

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form No. 1	paKe 0f 33

Date: 7/16/2018 (rev February 1, 2019)

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F11

Tank No. F"12

Tank No. F"13

Tank No. F"14

Tank No. F"15

1

Status of Tank (Mark only one)











A. Currently in Use

0

0

~

~

0

B Temporarily Out of Use
(Also complete Section XI)

~

~

0

0

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2

Date of Installation (mo/year)

02/1943

03/1943

03/1943

03/1943

04/1943

3.

Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)











B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 13 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No.F'11

Tank No. F'12

Tank No. F'13

Tank No. F'14

Tank No. F'15

E. Used Oil/Waste Oil



c





c





c





II





c



F. JP-4



n





II





II





~





II



G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

JP-5

JP-5

EMPTY

EMPTY

F-76

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes





Yes

6, Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic



~



~





c





~





~



ii. Steel



e





E





E





B





E



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic



~





~





~





~





~



ii. Steel



~





~





~





~





~



iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None



0





3





B





3





3



E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

[

~



I

~



I

~



1

~



[

~



ii. Double-walled steel

[

~



I

~



I

~



1

~



[

~



iii. Impressed current system

[

~



I

~



I

~



1

~



I

~



iv. Sacrificial anode system

I

~



I

~



[

~



1

~



[

~



v. Corrosion expert determination

[

~



[

~



[

~



1

~



[

~



vi. Other, please specify

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 14 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"11

Tank No. F"12

Tank No. F"13

Tank No. F~14

Tank No. F"15

C. Primary Containment Material or Single-Wailed Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.











v. None

0

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

0

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

0

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

0

0

0

0

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 15 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No.F"11

Tank No. F"12

Tank No.F-13

Tank No.F"14

Tank No.F"15

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

IZI

NA

0

NA

0

NA

0

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~ I

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 16 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE

Tank Number

Tank No. F"11

Tank No. F-12

Tank No. F13

Tank No. F"14

Tank No. F 15

1. Closing of Tank

A. Estimated date last used
(mo./day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

	

Tank Number

Tank No. F'11

Tank No. F"12

Tank No. F"13

Tank No. F"14

Tank No. F"15

A.

Date Repaired

N/A

N/A

N/A

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



c.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks • Form No. 1
Date: 7/16/2018 (rev February 1. 2019)

Page 17 of 33

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F"16

Tank No. F"17

Tank No. F"18

Tank No. F"19

Tank No. F~20

1.

Status of Tank (Mark only one)











A. Currently in Use

0

~

~

~

0

B. Temporarily Out of Use

(Also complete Section XI)

~

0

0

0

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

05/1943

05/1943

05/1943

06/1943

07/1943

3.

Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)











B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 18 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F~16

Tank No. F~17

Tank No. F"18

Tank No. F"19

Tank No. F"20

E. Used Oil/Waste Oil

~

~

" ~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-76

EMPTY

EMPTY

EMPTY

JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes







Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

12

0

0

0

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

0

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 19 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank Nc

F-16

Tanh

Nc

,.F-«

Tank No. F"18

Tank Nc

F-19

Tank No. F"20

C. Primary Containment Material or Single-Walled Piping



Fiberglass reinforced plastic



c





C





~





II





~





Flex piping



L





L





L





L





c





. Steel



E





E





E





E





E





Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic



C





C





II





C





~



ii. Flex piping



C





C





I





c





~



iii. Lined trench



G





c





~





L





~



iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None



0





E





E





0





E



E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel



~





~





~





~





~



ii. Impressed current system



~





~





~





~





~



iii. Sacrificial anode system



~





~





~





~





~



iv. Corrosion expert determination



~





~





~





~





~



v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

I

~





~





~





~



I

~



B. Safe Suction (no valve at tank)

I

~





~



I

~





~



I

~



C. Pressure

I

2



I

2



I

2





2



I

2



D. Not Applicable

I

~



I

~



I

~





~



I

~



9. Spill prevention equipment

I

~



I

~



I

~



I

~



I

~



A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

I

2



I

2



I

2





2





E



A. Automatic shutoff device (flapper)
Make and Model

I

~



I

~



I

~





~





L



B. Overfill alarm
Make and Model

I

2





2



/

0





E



C. Ball float valve
Make and Model

I

~





~





~



I

II





C



Notification for Underground Storage Tanks - Form No. X
Date: 7/16/2018 (rev February 1,2019)

Page 20 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank N

0 F-16

Tank No.F-17

Tank No.F"18

Tank No.F"19

Tank No.F"20

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

0

NA

0

NA

0

NA

~

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

n

NA

~

NA

~

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 21 of 33

-------
Facility ID No. 9-102271

XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE

Tank Number

Tank No. F"16

Tank No. F"17

Tank No. F'18

Tank No F"19

Tank No. F"20

1. Closing of Tank

A. Estimated date last used
(mo./day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F"16

Tank No. F"17

Tank No. F'18

Tank No. F"19

Tank No. F"20

A.

Date Repaired

N/A

N/A

N/A

N/A

N/A

B.

Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



C.

Select one of the following:

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.











iii. Manufacturer's installation
checklists have been completed
and documented











iv. Another method allowed by the
department. Please specify











Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 22 of 33

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified by number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F ST'

Tank No. F'ST2

Tank No. F"ST3

Tank No. F"ST4

Tank No. F""rE3

1.

Status of Tank (Mark only one)











A. Currently in Use

0

0

0

0

0

B. Temporarily Out of Use

(Also complete Section XI)

~

~

~

~

~

C. Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

07/1942

07/1942

07/1942

07/1942



3.

Estimated Capacity (gallons)

400,000

400,000

400,000

400,000

31,665



A. Compartmentalized? Yes/No

No

No

No

No

No



Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4.

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)











B, Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D. Kerosene

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 23 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"ST1

Tank No. F"ST2

Tank No. F"ST3

Tank No. F'ST4

Tank No. Pip"H

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-24

JP-5

F-24

F-76

F-24, F-76, JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

N/A

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

El

0

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

[3

El

0

0

~

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 24 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. F'ST1

Tank No. F"ST2

Tank No. F'ST3

Tank No. F"ST4

Tank No. P"""H

C. Primary Containment Material or Single-Wailed Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is above ground

Piping is above ground

Piping is above ground

Piping is above ground



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A

N/A

v. None

13

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

0

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

n

C. Pressure

~

~

~

~

0

D. Not Applicable

0

0

0

0

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)

N/A

N/A

N/A

N/A

N/A

10. Overfill prevention equipment

0

0

0

0

~

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

0

0

0

~

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 25 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No.F ST1

Tank No. F="ST2

Tank No.F ST?

Tank No.F 574

Tank No. """13

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

El

NA

0

NA

El

NA

0

NA

~

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)
If YES, specify type.

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

m

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 26 of 33

-------
Facility ID No. 9-102271
XI. TANK(S) OUT OF USE OR CHANGE IN SERVICE	

Tank Number

Tank No. F_ST1

Tank No. F ST2

Tank No. F-ST3

Tank No. F"ST4

Tank No. """n

1. Closing of Tank

A. Estimated date last used
(mo./day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)











XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No. F"ST1

Tank No. F"ST2

Tank No. F"ST3

Tank No. F"ST4

Tank No. p"*"ri

A. Date Repaired

06/19/2021

N/A

N/A

N/A

N/A

B. Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)



Tank F-ST1:











Contractor completed a comprehensive out-of-service integrity inspection and repair of Surge Tank 1. Completed repairs
included weld repairs to inlet/outlet nozzle, new steel floor, six shell patch plates and new stilling well and drain line. Installation
of new steel floor included geotextile fabric, flexible membrane liner, and concrete infill, which was slotted to create a leak
detection system. Based on inspection of the repairs and review of documentation of the repairs, the Engineer of Record
determined Surge Tank 1 is suitable to return to service, as specified in the Contractor's Suitability for Service Testament
(attached).

Leak detection testing of Surge Tank 1 was performed, with no detectable leak above test method's minimum detectable leak
rate, resulting in a passing test. The leak detection testing conducted meets the regulatory requirements in HAR 11-280.1-43
(10). The Executive Summary of the 2021 Annual Leak Detection Testing Report of Bulk Field-Constructed Surge Tank 1 is
attached.

C. Select one of the following:

N/A

N/A

N/A

N/A

N/A

i. Installation certified by tank and
piping manufacturers











ii. Installation inspected by a
registered engineer.

Yes

N/A

N/A

N/A

N/A

iii. Manufacturer's installation
checklists have been completed
and documented

N/A

N/A

N/A

N/A

N/A

iv. Another method allowed by the
department. Please specify

N/A

N/A

N/A

N/A

N/A

Notification for Underground Storage Tanks - Form No. 1	p „ 27 of 33

Date: 7/16/2018 (rev February 1, 2019)

-------
Facility ID No. 9-102271

VII. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings:

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in
Sections IX and X), and associated pipings; and

H.	Indication of North/South direction.

VIII. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

IX. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. JUS

Tank No. ^J|

Tank No. BirO

Tank No. e""t3

Tank No.

1.

Status of Tank (Mark only one)











A. Currently in Use

0

0

0

0

~

B. Temporarily Out of Use

(Also complete Section XI)

~

~

~

~

~

C Permanently Out of Use

(Also complete Section XI)

~

~

~

~

~

2.

Date of Installation (mo/year)

07/2010

05/2006

09/2011

06/2006



3.

Estimated Capacity (gallons)

2,000

4,000

59,500

236,579





A. Compartmentalized? Yes/No

No

No

No

No





Estimated compartment capacity
(gallons)













B. Manifolded? Yes/No

No

No

No

No



4

Substance Currently or Last Stored in Greatest Quantity by Volume







A. Gasoline (Specify product grade)











B. Diesel

~

~

~

~

~

C. Gasohol (Including ethanol blends)
Specify product grade











D. Kerosene

~

~

~

~

~ I

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 28 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. PI!T'B

Tank No. PRTfl

Tank No. °Hfl

Tank No. EwaB

Tank No.

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A



H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A



1. Other, please specify.

F-24

F-24

F-24

F-24



5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes



6. Tank (Mark all that apply)

A. Manufacturer and Model

Steel Tank
lnstitute/STI-P3

Steel Tank
lnstitute/STI-P3

N/A

N/A



B. Underwriters Laboratory No.

UL-58

UL-58

N/A

N/A



C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

12

0

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A



iv. None

~

~

~

~

~

E. Corrosion Protection (except fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

0

0

~

~

~

iii. Impressed current system

0

0

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A



7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown



B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown



Notification for Underground Storage Tanks - Form No. 1
Date: February 1, 2019

Page 29 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. ""'El

Tank No. "Tfl

Tank No. °"*B

Tank No. "B

Tank No.

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

n

~

~

~

iii. Steel

0

0

0

0

~

iv. Other, please specify.

N/A

N/A

N/A

N/A



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

0

0

~

~

~

iv. Other, please specify.

N/A

N/A

N/A

N/A



v. None

~

~

0

0

~

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

0

0

0

0

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A



8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

~

~

0

0

~

D Not Applicable

0

0

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A



B. Capacity (gallons)

N/A

N/A

N/A

N/A



10. Overfill prevention equipment

0

0

~

~

~

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

Veeder-Root
US-350 PLUS

0

Veed«r-Root
TLS-350 PLUS



~

~

C. Ball float valve
Make and Model

~

~

~

~

~

Notification for Underground Storage Tanks • Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 30 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank K

o.ra.

Tank No.

Tank No. °""B

Tank No.E"tt

Tank No.

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

0

NA

0

NA

B. Tank tightness testing

~

NA

~

NA

~

NA

o

NA

O

NA

C. Inventory control

~

NA

~

NA

~

NA

o

NA

0

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

o

NA

0

NA

E. Vapor monitoring

~

~

~

~

~

~

0

O

0

0

F. Groundwater monitoring

~

~

~

~

~

~

0

0

0

O

G. Interstitial monitoring

El

~

0

~

~

~

o

0

o

0

H. Statistical inventory reconciliation

~

~

~

~

~

~

0

0

o

0

I. Automatic line leak detectors (Yes/No)
If YES, specify type

NA

N/A

NA

N/A

NA

N/A

NA

N/A

NA

N/A











J. Line tightness testing

NA

0

NA

0

NA

0

NA

0

NA

0

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A





X. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/20X8 (rev February 1,2019)

Page 31 of 33

-------
Facility ID No. 9-102271

Tank Number

Tank No. ""'B

Tank No. "Tfl

Tank No.

Tank No. C-"B

Tank No.

1. Closing of Tank

A. Estimated date last used
(mo./day/year)











B. Estimated date tank closed
(mo./day/year)











C. Tank was removed from ground











D. Tank was closed in ground











E. Tank filled with inert material
Describe











F. Change in service











2. Site Assessment Completed (Y/N)











3. Evidence of a Leak Detected (Y/N)









J

XII. CERTIFICATION OF COMPLIANCE FOR REPAIRS (Complete for each tank at this location)

Tank Number

Tank No.

Tank No.

Tank No.

Tank No.

Tank No.

A. Date Repaired

N/A

N/A

N/A

N/A

B. Provide description of repair along with the Tank Number (Attach additional sheet if necessary.)

C. Select one of the following:

i. Installation certified by tank and
piping manufacturers

ii. Installation inspected by a
registered engineer.

iii. Manufacturer's installation
checklists have been completed
and documented

iv Another method allowed by the
department. Please specify

Notification for Underground Storage Tanks - Form No. 1
Date: 7/16/2018 (rev February 1, 2019)

Page 32 of 33

-------
Facility ID No. 9-102271

XIII. CERTIFICATION (Read and sign after completing all sections)

I certify under penalty of law that I have personally examined and am familiar with the information submitted in this and all attached
documents, and that based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the
submitted information is true, accurate, and complete.

(b) (6)

Print or Type Name of owner or owner's authorized representative

Signature

(b) (6)

Regional Environmental Program Director
Official Title

I 6 OaJ ^Q2LI

Date Signed

Status of Signatory (Mark as appropriate)

1.	Corporation:

2.	Partnership:

3.	Sole proprietorship:

4.	Government entity:

Q principal executive officer
~duly authorized representative
Qgeneral partner
f~| proprietor

~ principal executive officer
Q ranking elected official

Notification for Underground Storage Tanks • Form No. 1
Date: 7/16/2018 (rev February 1,2019)

Page 33 of 33

-------
A

JUL 2 2 202

ENGINEERING, INC.

SUITABILITY FOR SERVICE TESTAMENT
SURGE TANK 1 (FACILITY NO. 1224)

Enterprise Engineering Inc. (EEI). under contract to APTIM (NAVFAC EXWC Contract No. N39430-
15-D-1632, Task Order 3974318F4132), completed a comprehensive, out-of-service external and internal
integrity inspection and suitability for service evaluation of Surge Tank 1 at NAVSUP FLC Pearl Harbor,
Hawaii. The out-of-service inspection was performed from August 10 through August 24, 2020.
Subsequently, APTIM completed repairs identified in the Statement of Work and EEI's Final Condition
Assessment Report (Pre-Repair) dated October 2020.

EEI performed a post-repair inspection of Tank 1 on April 19, 2021. The inspection determined repairs
are complete except for the vent line screen which will be completed after the ventilation hose is
removed, prior to placing the tank back in service. All repairs are in accordance with the repair design
documents. This report provides a summary of the repairs identified in EEI's Final Condition Assessment
Report (Pre-Repair), the status of repairs, a revised DLA-E Tank Condition Fonn (Post-Repair), and the
Final Condition Assessment Report (Pre-Repair).

EEI recommends the next internal out-of-service inspection be scheduled no later than April 2031 (10
years after the April 2021 inspection), or sooner if a change in condition has occurred.

Based on the inspection of the repairs and review of the repair documentation,
EEI has determined Tank 1 is suitable to return to service





O- %

(b)(4)

* =

\ [^^4/29/202^ qt J

wWg'W

POST-REPAIR

(b) (4)

API 653 AST Inspector Certificate No.

(b)(4)

"(b) (4)

API 653 AST Inspector Certificate No.

April 28. 2021

Date

April 28. 2021
Date

Surge Tank 1 — Post Repair Inspection
NAVSUP FLC JB Pearl Harbor-Hickam. HI (PRL)
EEI Project No.: 9219

SUITABILITY FOR SERVICE TESTAMENT

April 2021

ENCLOSURES)

-------
JUL 2 2 2021

APTIM | Government Services
12005 Ford Road; Suite 600
Dallas, TX 75234

FISC Red Hill
Pearl Harbor, HI

Scope of Work:	Furnish required management, labor, services, materials and equipment to

perform the required annual tightness testing of Tank # S1224 (Surge 1) an
underground fuel storage tank located at FISC Red Hill, Pearl Harbor, HI.

Summary

Testing of Tank # S1224 (Surge 1) a 420,000-gal underground storage tank located at FISC Red Hill,
Pearl Harbor, Hawaii commenced June 16, 2021 and was completed June 19, 2021. The result of that
testing is that the tank system is determined to be tight to isolation. Testing was performed using
the	protocols set out in the third-party evaluations. All tank valves

were adequately secured such that any fluid loss was isolated to leakage. Therefore, the
containment integrity of the tank was not compromised and the test is considered conclusive.

Tank # S1224 (Surge 1): After 72 hours of testing the tank is certified to be tight.

ENCLOSURES

-------
DEPARTMENT OF THE NAVY

COMMANDER
NAVY REGION HAWAII
850 TICONDEROGA ST STE 110
J8PHH, HAWAII 96860-5101

5750

Ser N4/0533
May 15,2019

may 232019^?

CERTIFIED NO: 7016 0910 0001 0891 7390

Ms. Roxanne Kwan
Hawaii State Department of Health
Environmental Management Division
Solid and Hazardous Waste Branch
Underground Storage Tank Section
2827 Waimano Home Road #100
Pearl City, HI 96782

Dear Ms. Kwan:

SUBJECT: UST PERMIT APPLICATION FOR RED HILL BULK FUEL STORAGE
FACILITY, JBPHH, OAHU, DOH FACILITY ID NO. 9-102271

The Navy submitted a permit application on 13 March 2019 for Red Hill Bulk Fuel Storage
Facility (RHBFSF). Based upon DOH feedback, the application has been revised and shall
replace the original submittal.

This letter and its enclosures provide information that does not fit into the application form
"Application for an Underground Storage Tank Permit - Form No. 2" and are incorporated into
the permit application.

The confidential/redacted information has been provided in full to the DOH; however, the
Navy considers this information to be confidential under the Hawaii Revised Statutes (HRS)
342L-15 and does not concur with and will not allow its public release. The documents
containing the exact location of the sensitive infrastructure comprising the system to include
pipelines, hydrants, fill stands, etc. is for official use only and cannot be disclosed to the public
because the impact of any damage caused to this system is so great, that it could cause
irreparable harm to the government. Additionally, the technology and methodology used in
these reports is proprietary to the contractor. Disclosure of their processes and procedures would
result in significant competitive harm to the contractors. The government is bound not to
disclose the information for other than official use by contract, federal law, and the Trade Secrets

Act.

The revised Application for an Underground Storage Tank Permit - Form No. 2 is being
submitted as Enclosure 1.

-------
5750

Ser N4/0533
May 15, 2019

A Location Map of the Red Hill storage tanks is provided as Enclosure 2. A Location Map of
the surge tanks and piers is provided as Enclosure 3. A Location Map of the Hickam airfield
hydrant system, which includes hydrant pits and product recovery tanks, is provided as
Enclosure 4.

Primary Containment Material

The RHBFSF tanks F-l to F-20 and F-ST1 to F-ST4 are constructed of reinforced concrete
and lined with steel. The primary containment material is steel.

Facility Piping

Tank and piping diagrams for Defense Fuel Support Point (DFSP) Pearl Harbor and Hickam
Airfield Hydrant System are provided as Enclosure 5. The diagrams indicate which segments of
piping are in contact with the ground and have corrosion protection (dashed line), and which
segments are above ground (solid line). All piping is single wall steel.

Piping - Release Detection

The piping for tanks F-l to F-20 and F-ST1 to F-ST4 that is located between the tank and the
first valve (nozzle piping) is considered and tested as part of the RHBFSF tanks. Information on
tank tightness testing is presented in the "Tanks - Release Detection" section, below.

The piping located inside the RHBFSF tunnel is above ground; therefore, no release detection
method for this above ground piping is checked in Section XI.11 on pages 6, 10, 14, 18, and 22
of the permit application form.

A line tightness test is performed annually on petroleum pipeline segments located outside the
RHBFSF tunnel and fully or partially in contact with the ground. In January 2019, the leak
detection rate per test section volume met the requirements of HAR §11 -280.1 -44(4)(A)(i),
except for one pipeline section. This pipeline section was subsequently removed from service
until it is repaired by replacement. See excerpts from the 2019 Annual Leak Detection Testing
Report of^^Sections	of Petroleum Pipelines of March 2019, which are provided

as Enclosure 6. Information on the petroleum pipeline segments located outside the RHBFSF
tunnel and fully or partially in contact with the ground is presented on pages 19 to 22 of the
permit application form, in the column labeled "Pipelines Located Outside Tunnel."

An annual static liquid pressure test is performed on pier pipelines to confirm that no leaks
occur under static liquid pressure at least 1.5 times the maximum allowable working pressure as
required in 33 CFR 156.170. This meets the requirements of HAR §1 l-280.1-44(4)(A)(i). In
January 2019, the pier pipelines passed the annual static pressure testing. See excerpts from the

2

-------
5750

Ser N4/0533
May 15,2019

2019 Annual Static Liquid Pressure Testing Report of^^^QSections (BUB) °f Petroleum
Pier Pipelines of March 2019, which arc provided as Enclosure 7.

The annual line tightness test of the piping associated with tanks PRT-Diamond Head and
PRT-Ewa meets the requirements of HAR §1 l-280.1-44(4)(A)(i). Results for the January 2019
leak detection testing are presented in Table 2-1 of Enclosure 6. Test Section 10, "Type III PRT
Issue," is the piping associated with tank PRT-Ewa, and Test Section 13, "AMC PRT Issue," is
the piping associated with tank PRT-Diamond Head.

Piping - Cathodic Protection

All piping segments that are in contact with the ground are protected by an impressed current
cathodic protection system. A detailed description of the system, including a description of
rectifiers, system drawings, and location of anode beds, can be found in the two most recent
Annual Pearl Harbor Cathodic Protection Survey Reports and Annual Hickam Cathodic
Protection Survey Reports. Excerpts from these reports are provided as Enclosures 8 and 9,
respectively.

Product Recovery Tanks

Tanks PRT-Diamond Head and PRT-Ewa are protected by an impressed current cathodic
protection system. A detailed description of the system, including a description of the rectifiers,
system drawings, and location of anode beds, can be found in the two most recent Hickam
Cathodic Protection Survey Reports. Excerpts from these reports are provided as Enclosure 9.

Tanks - Release Detection

A tank tightness test is performed on tanks F-2 to F-18 and F-20, and tanks F-ST1 to F-ST4
semi-annually, unless they have been emptied for the Clean, Inspect, Repair (CIR) process. The
tank tightness test meets the 0.5 gallon per hour leak rate as specified in HAR
§ 11 -280.1 -43(10)(A). See excerpts from the Final 2018 Annual Leak Detection Testing Report
of 17 Bulk Field-Constructed Underground Storage Tanks at Red Hill Fuel Storage Complex of
January 2019, which are provided as Enclosure 10.

Method of Product Dispensing

Tanks F-ST1 to F-ST4 are not storage nor dispensing tanks, instead they serve as surge tanks
to allow for the buffering of product pressure throughout the system during product movement.
They have no ability to dispense fuel.

3

-------
5750

Ser N4/0533
May 15, 2019

Overfill Prevention Equipment

Tanks F-l to F-20 and F-ST1 to F-ST4 are equipped with an Automated Fuel Handling
Equipment (AFHE) Industrial Control System (ICS) inventory monitoring based on Automatic
Tank Gauging (ATG) equipment overflow protection sensors and equipment that de-energizes
the pump and shuts an isolation valve to prevent overfilling each UST once the fuel level in the
tank reaches no more than 95% full.

The AFHE system operates 24 hours a day, 365 days a year, and is a continuously manned and
monitored system, equipped with both a high and high-high level alarm, with high alarms set at a
level of no more than 90% full.

Airfield Piping

Information on the airfield piping has been added to pages 23 to 26 of the UST permit
application form. All of the piping is underground, as shown in Enclosure 5 and the figures of
Enclosure 6. Table 2-1 of Enclosure 6 provides a summary of the 2019 annual leak detection
testing results for each of the 21 sections of airfield piping. Test sections 11, 12, 13, 14, 15, 20
and 21 are associated with the Diamond Head Piping Loop. The other fourteen sections are
associated with the Ewa Piping Loop.

If you have any questions regarding this matter or need any additional information, contact

or by email at

(b) (6)

(b) (6) |

(b) (6)



Sincerely,

M. R. DEhAO
Captain, CEC, U.S. Navy
Regional Engineer
By direction of the
Commander

4

-------
5750

Ser N4/0533
May 15,2019

Enclosures:

1.	Revised DOH Form No. 2, Application for an Underground Storage Tank Permit for Red
Hill Bulk Fuel Storage Facility, DOH Facility ID No. 9-102271 of May 15, 2019

2.	Location Map of Red Hill Storage Tanks

3.	Location Map of Surge Tanks and Piers

4.	Location Map of Hickam Airfield Hydrant System

5.	REDACTED - Tank and Piping Diagrams for DFSP Pearl Harbor and Hickam Airfield
Hydrant System

6.	REDACTED - Excerpts from 2019 Annual Leak Detection Testing Report Sections

of Petroleum Pipelines of 14 March 2019, prepared for Defense Logistics
Agency Energy, submitted by Michael Baker International

7.	REDACTED - Excerpts from 2019 Annual Static Liquid Pressure Testing Report ofi
Sections	°f P^lroleum Pier Pipelines of March 2019, prepared for Defense
Logistics Agency Energy, submitted by Michael Baker International

8.	REDACTED - Excerpts from July 2017 and February 2018 Annual Pearl Harbor Cathodic
Protection Survey Reports

9.	REDACTED - Excerpts from September 2016 and January 2018 Annual Hickam Cathodic
Protection Survey Reports

10.	REDACTED - Excerpts from Final 2018 Annual Leak Detection Testing Report of 17 Bulk
Field-Constructed Underground Storage Tanks at Red Hill Fuel Storage Complex, Joint
Base Pearl Harbor-Hickam, Hawaii of 23 January 2019, prepared for Defense Logistics
Agency Energy, submitted by Michael Baker International

5

-------
5750

Ser N4/0533
May 15,2019

Blind copy (via email) to;

|, NAVSUP FLC Pearl Harbor
NAVSUP FLC Pearl Harbor
|, NAVSUP FLC Pearl Harbor
NAVFAC HI Counsel

6

-------
Enclosure 1

-------
SOLID AND HAZARDOUS WASTE BRANCH

Underground Storage Tank Program	MAY 2 3 2019-^5^

2827 Waimano Home Road #100 • Pearl City, Hawaii 96782
Phone: 808 - 586- 4226 • Fax: 808-586-7509 • http://health.hawaii.gov/shwb/undergruund-storage-tankis/

CNRH LETTER 5750 SER N4/0533 OF MAY 15, 2019 IS INCORORATED BY REFERENCE
AND MADE A PART OF THIS APPLICATION

APPLICATION FOR AN UNDERGROUND STORAGE TANK PERMIT

Return completed form to:

Solid and Hazardous Waste Branch
Underground Storage Tank Program
2827 Waimano Home Road #100
Pearl City, Hawaii 96782

Facility ID Number: 9-102271

Type Of Notification:

I [installation and Operation ($300)

State Use Only

Date received:

Permit Number:

Permit Fee:

Date Paid:

Receipt Nunmber:

Comments:

I ^ loperation ($300)



Zl Modification - except for temporary & permanent closure ($200)







I. LOCATION OF TANK(S)

Red Hill Bulk Fuel Storage Facility



Facility Name or Company Site identifiers

Location Contact Person

Red Hill

Aiea Hawaii 96701 Oahu ««»«<*. mmr nmwa. hoimm

Location Address (P.O. Box not acceptable)

City State Zip Code Island Tax Map Key#
(808) 473-7815

Location Phone # (w/ area code)

Location Fax # (w/ area code)



CONTACT PERSON IN CHARGE OF TANK(S)

Regional Fuels Officer

Name

1942 Gaffney Street, Suite 100

Job / Position Title
JBPHH HI 96860

Mailing Address

City State Zip Code

i^Bb

(808) 4/3-/816

Phone # (w/ area code)

Fax # (w/ area code) E-mail Address

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 1 of 27

-------
Facility ID No. 9-102271

III. OWNER OF TANK(S)

US Navy - COMNAVREG HI

Owner Name (Corporation, Individual, Public Agency, or Other Entity)







850 Ticonderoga Street, Suite 110

JBPHH

HI

96860

Mailing Address

City

State

Zip Code

(808) 471 -3926 (808) 473-5024



marc.delao@navy.mil



Phone # (w/ area code)	Fax# (w/ area code)	E-mail Address

IV. OPERATOR OF TANK(S) (if same as Section III, check here ~ )

Naval Supply Systems Command Fleet Logistics Center Peari Harbor

Operator Name (Corporation, Individual, Public Agency, or Other Entity)







1942 Gaffney Street, Suite 100

JBPHH

HI

96860

Mailing Address

City

State

Zip Code

(808)473-7815





¦

Phone # (w/ area code)	Fax # (w/ area code)	E-mail Address

V. CONTRACTOR

N/A	N/A

Company Name



Contact Person Name

N/A

N/A

N/A

Mailing Address

City

State Zip Code





N/A

Phone # (w/ area code)	" Fax # (w/ area code)	E-mail Address

VI. TYPE OF OWNER

BFederal Government (Military) LJFederal Government (Non-Military) LJ
Local Government	I	I Marketer	I	|

State Government
Non-Marketer

VII. TYPE OF FACILITY (Select the appropriate facility description)

I I Airline
I I Auto Dealership
I I Baseyard
I I Car Rental
I I Cleaner/Laundromat
EDCommunication Sites

EHcontractor
EHFarm
EUFire Station
EH Gas Station
EHGolf Course

EH Hospital

EZIPetroleum Distributor
EHpolice Station
I I Residential
EH Resort/Hotel
EHschool

EHservi'ce Centers/Auto Repair/Maintenance
I iTruckino/Transporter
I IUtilities

EHwastewater Treatment Plants
EH Wholesaler/Retailer

[/]Other (Explain) Fuel Storage and Airfield Hydrant System

Application for an Underground Storage Tank Permit - Form No. 2	Page 2 of 27

Date: July 16,2018

-------
Facility ID No. 9-102271

VIII. FINANCIAL RESPONSIBILITY (Check all that apply)

EZIcommercial Insurance	CZD Letter of Credit	I I Local Government Bond Rating Test

dlFinancial Test of Self Insurance	dsurety Bond	EZiother Method Allowed (Specify)	

[^Guarantee	dlTmst Fund	0Exempt: dlstateor 0Federal Agency

IX. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified by number/s consistent with the tank & dispenser pump numbers in

Sections XI and XII), and associated pipings; and

H.	Indication of North/South direction.

X. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located.

XI. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No

F-1

Tank No. ^-2

Tank

No

F-3

Tank No

. F-4

Tank No. F-5

1. Status of Tank (Mark only one)

A. Currently in Use



~





0





Z



[

2





c



B. Temporarily Out of Use



0





~





~



[

~





E



2. Date of Installation (month/year)

10/1942

09/1942

01/1943

11/1942

12/1942

3. Estimated Capacity (gallons)

12,000,000

12,000,000

12,000,000

12,000,000

12,700,000

A. Compartmentalized? Yes/No

No

No

No

No

No

Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4. Substance Stored

A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel



~





~





~





C



[

~



C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene



~





~



~





C









Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 3 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No. F-1

Tank No. F-2
~

Tank No. F-3

Tank No. f7"4

Tank No. ^-5

E. Used Oil/Waste Oil

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

EMPTY

F-24

F-24

F-24

EMPTY

5. Substance Compatible with
Tank and Piping? Yes/No

N/A

Yes

Yes

Yes

N/A

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

0

0

0

iii. Other, please specify.











D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

0

0

0

0

0

E. Corrosion Protection (except Fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 4 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No.

Tank No.

Tank No.

Tank No.

Tank No.

C. Primary Containment Material or Single-Walled Piping





i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

C
IZ



~

~

iii. Steel

0

13



0

0

iv. Other, please specify.

Piping is
above ground

Piping is
above ground

Piping is
above ground

Piping is
above ground

Piping is
above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.











v. None

13

13



/



0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

0

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)











10. Overfill prevention equipment

13

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

See cover letter

0

See cover letter

See c

/

ove

r letter

0

See cover letter

/

See cover letter

C. Ball float valve
Make and Model

~

~

~

~

~

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 5 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No.

Tank No. F'?

Tank No. F-3

Tank No. p-4

Tank No. ^-5

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

~

NA

E

NA

0

NA

0

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

n

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

1. Automatic line leak detectors (Yes/No)

NA

No

NA

No

NA

No

NA

No

NA

No

If YES, specify type.











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department Please specify





















XII. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 6 of 27

-------
Facility ID No. 9-102271

VIII. FINANCIAL RESPONSIBILITY (Check all that apply)

EUcommercial Insurance [ZULetter of Credit dLocal Government Bond Rating Test
IZZ]Financial Test of Self Insurance	EZlsurety Bond	IZZIother Method Allowed (Specify)	

OGuarantee	EUtrust Fund	0Exempt: dlstateor 0Federal Agency

IX. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified by number/s consistent with the tank & dispenser pump numbers in

Sections XI and XII), and associated pipings; and

H.	Indication of North/South direction.

X. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located

XI. DESCRIPTION OF TANK(S) (Complete for each tank at this location)



Tank No. F-6

Tank No

F-7

Tank

No.f±

Tank

-

No

.

F-9

Tank

No."0

1. Status of Tank (Mark only one)

A. Currently in Use



0





E





E



[

2





E



B. Temporarily Out of Use



~





~





~



[

~





C



2. Date of Installation (month/year)

12/1942

05/1943

03/1943

02/1943

01/1943

3. Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000

A. Compartmentalized? Yes/No

No

No

No

No

No

Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4. Substance Stored

A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel



~





~





~





C



I

~



C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene



~





~



~





C



I

~



Application for an Underground Storage Tank Permit - Form No. 2	Page 7 of 27

Date: July 16, 2018

-------
Facility ID No. 9-102271

Tank Number

Tank No F-6

—|-j-H

Tank No. ^
~

Tank No F-8

r~n 1

Tank No. ^-9
~

Tank No. F"10

E. Used Oil/Waste Oil

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-24

JP-5

JP-5

JP-5

JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

0

0

0

iii. Other, please specify.











D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

0

0

0

0

~

E. Corrosion Protection (except Fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 8 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No.

Tank No. ^-7

Tank No.

Tank No.

Tank No. F'10

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

E

El

0

El

El

iv. Other, please specify.

Piping is
above ground

Piping is
above ground

Piping is
above ground

Piping is
above ground

Piping is
above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.











v. None

/

El

/

El

El

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

El

El

El

El

El

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)











10. Overfill prevention equipment

El

El

El

El

El

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

El

See cover letter

El

See cover letter

El

See cover letter

El

See cover letter

El

See cover letter

C. Ball float valve
Make and Model

~

~

~

~

~

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 9 of 27

-------
Facility ID No. 9-102271

Tank Number

tank No. F-6

Tank No. F"7

Tank No. F-8

Tank No. F"9

Tank No.F'10

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

IMA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing •

0

NA

13

NA

0

NA

12

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)

NA

No

NA

No

NA

No

NA

No

NA

No

If YES, specify type.











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify





















XII. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 10 of 27

-------
Facility ID No. 9-102271

VIII. FINANCIAL RESPONSIBILITY (Check all that apply)

[^Commercial Insurance CZlLetter of Credit EUl-Ocal Government Bond Rating Test
EHFinancial Test of Self Insurance	EUsurety Bond	EZIother Method Allowed (Specify)	

EUGuarantee	dlTrust Fund	0Exempt: IZHstate or 0Federal Agency

IX. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified by number/s consistent with the tank & dispenser pump numbers in

Sections XI and XII), and associated pipings; and

H.	Indication of North/South direction.

X. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located.

XI. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

c n

Tank No.

Tank No

F-12

Tank No. F"13

Tank No



Tank No

F-15

1. Status of Tank (Mark only one)

A. Currently in Use



0





0





c



[

~





\L



B. Temporarily Out of Use



~





~





z



[

2





C



2. Date of Installation (month/year)

02/1943

03/1943

03/1943

03/1943

04/1943

3. Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000

A. Compartmentalized? Yes/No

No

No

No

No

No

Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4. Substance Stored

A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel

I

~





~



I

~





E



I

~



C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene

I

~



I

~











C



I

~



Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16,2018

Page 11 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No [~"11

Tank No. F~12

Tank No. F"13

Tank No. F~14

Tank No. F~15

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

JP-5

JP-5

EMPTY

EMPTY

F-76

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

N/A

N/A

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

0

0

0

iii. Other, please specify.











D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

0

0

0

0

0

E. Corrosion Protection (except Fiberglass reinforced plastic tanks)

i. Fiberglass coated steel

~

~

~

~

~

ii. Double-walled steel

~

~

~

~

~

iii. Impressed current system

~

~

~

~

~

iv. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 12 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No. M1

Tank No. F_12

Tank No. F"13

Tank No. M4

Tank No. F"15

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

[3

0

0

0

0

iv. Other, please specify.

Piping is
above ground

Piping is
above ground

Piping is
above ground

Piping is
above ground

Piping is
above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.











v. None

/

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

0

0

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)











10. Overfill prevention equipment

0

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

See cover letter

~

See cover letter

/

See cover letter

/

See cover letter

0

See cover letter

C. Ball float valve
Make and Model

~

~

~

~

~

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 13 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No.W

-*¦ 0 "I"".' ]

Tank No.f-1?

Tank No F"13

tank N

o F"14

-p . .

Tank N

O F-15

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

0

NA

0

NA

13

NA

0

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)

NA

No

NA

No

NA

No

NA

No

NA

No

If YES, specify type.











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

~

K. Other method approved by the
Department. Please specify





















XII. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

V ' ' . ' ; " ; ¦ •' "

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 14 of 27

-------
Facility ID No. 9-102271

VIII. FINANCIAL RESPONSIBILITY (Check all that apply)

EZlcommercial Insurance ~ Letter of Credit EZILocal Government Bond Rating Test
EHFinancial Test of Self Insurance	EHsurety Bond	EHother Method Allowed (Specify)	

EHGuarantee	EZlTrustFund	0Exempt: EHstateor 0Federal Agency

IX. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified bv number/s consistent with the tank & dispenser pump numbers in

Sections XI and XII), and associated pipings; and

H.	Indication of North/South direction.

X. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located.

XI. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No. F"16

Tank No

F-17

Tank No. F"18

Tank No

F-19

Tank No. F"20

1. Status of Tank (Mark only one)

A. Currently in Use



0





~





[7



[

~





E



B. Temporarily Out of Use



~





0





~



[

3





C



2. Date of Installation (month/year)

05/1943

05/1943

05/1943

06/1943

07/1943

3. Estimated Capacity (gallons)

12,700,000

12,700,000

12,700,000

12,700,000

12,700,000

A. Compartmentalized? Yes/No

No

No

No

No

No

Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4. Substance Stored

A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel



~





~





~





C



I

~



C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene



~





~











C



I

~



Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 15 of 27

-------
Facility ID No.

9-102271

Tank Number

Tank No. F"16

Tank No. F~17

Tank No. F~18

Tank No. F~19

Tank No. F~20

E.

F.

Used Oil/Waste Oil

~

~

~

~

~

JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-76

EMPTY

JP-5

EMPTY

JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

N/A

Yes

N/A

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank



Fiberglass reinforced plastic

~

~

~

~

~



i. Steel

0

0

0

0

0



ii. Other, please specify.











D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A

N/A

iv. None

0

0

0

0

0

E. Corrosion Protection (except Fiberglass reinforced plastic tanks)



Fiberglass coated steel

~

~

~

~

~



i. Double-walled steel

~

~

~

~

~



ii. Impressed current system

~

~

~

~

~



v. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A

N/A

7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 16 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No. F"16 Tank No. F"17

Tank No. F~18

Tank No. M9

Tank No. F'20

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

13

0

0

0

0

iv. Other, please specify.

Piping is
above ground

Piping is
above ground

Piping is
above ground

Piping is
above ground

Piping is
above ground

D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.











v. None

0

0

0

[3

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

~

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A

N/A

8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~	

~

~

~ "

C. Pressure

El

12

0

0

0

D. Not Applicable

~

~

~

~

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)











10. Overfill prevention equipment

0

0

0

0

0

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

/

See cover letter

0

See cover letter

/

See cover letter

0

See cover letter

0

See cover letter

C. Ball float valve
Make and Model

~

~

~

~

~

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 17 of 27

-------
Facility ID No. 9-102271

. , ... .... .. ,, . „ . , . .. l '1 — 		.¦

Tank Number

. , , ... ,,,,, . , ,
Tank No.1 16

Tank No.

Tank No.F'18

Tank No/"19

Tank No/ 20

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

0

NA

0

NA

0

NA

~

NA

0

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

O

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

O

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

0

~

I. Automatic line leak detectors (Yes/No)

NA

No

NA

No

NA

No

NA

No

NA

No

If YES, specify type.











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

0

K. Other method approved by the
Department. Please specify





















XII. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

'r-' 'V- . ..." ' . ¦ ;5.,'

Manufacturer of Dispenser

.

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 18 of 27

-------
Facility ID No. 9-102271

VIII. FINANCIAL RESPONSIBILITY (Check all that apply)

EHcommercial Insurance	EZ] Letter of Credit	IZH Local Government Bond Rating Test

EH Financial Test of Self Insurance	EH Surety Bond	EH Other Method Allowed (Specify)	

EHGuarantee	EHlrustFund	0Exempt: EHstate or 0Federal Agency

IX. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified by number/s consistent with the tank & dispenser pump numbers in

Sections XI and XII), and associated pipings; and

H.	Indication of North/South direction.

X. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located.

XI. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No

F-ST1

Tank No

F-ST2

Tank No

F-ST3 •

Tank No

F-ST4 .

Pipelines Located
Outside Tunnel

1. Status of Tank (Mark only one)

A. Currently in Use



0





0





E



[

0





E



B. Temporarily Out of Use



~





~





~



[

~





c



2. Date of Installation (month/year)

07/1942

07/1942

07/1942

07/1942



3. Estimated Capacity (gallons)

400,000

400,000

400,000

400,000

31,665

A. Compartmentalized? Yes/No

No

No

No

No

No

Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

No

4. Substance Stored

A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel



~





~



I

~





c





~



C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene



~





~



~





c





~



Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 201S

Page 19 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No.F STi

Tank No r'p12

Tank No c-313

Tank No. F"ST4

Pipelines Located
Outside Tunnel

E. Used Oil/Waste Oil

~

~

~

~

~

F. JP-4

~

~

~

~

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A

N/A

H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A

N/A

1. Other, please specify.

F-24

JP-5

F-76

F-76

F-24, F-76, JP-5

5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes

Yes

6. Tank (Mark all that apply)

A. Manufacturer and Model

Field-
constructed

Field-
constructed

Field-
constructed

Field-
constructed

N/A

B. Underwriters Laboratory No.

N/A

N/A

N/A

N/A

N/A

C. Primary Containment Material or Single-Walled Tank



Fiberglass reinforced plastic

~

~

~

~

~



i. Steel

0

0

0

0

~



ii. Other, please specify.











D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

~

~

~

~

~

iii. Other, please specify.

N/A

N/A

N/A

N/A



iv. None

0

0

0

0

~

E. Corrosion Protection (except Fiberglass reinforced plastic tanks)



Fiberglass coated steel

~

~

~

~

~



i. Double-walled steel

~

~

~

~

~



ii. Impressed current system

~

~

~

~

~



v. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A

N/A

N/A



7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown

Unknown

B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown

Unknown

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 20 of 27

-------
Facility ID No. 9-102271

Tank Number

Tank No. F_ST1

Tank No. F"ST2

Tank No. F ST3

Tank No. F_ST4

Pipelines Located
Outside Tunnel

C. Primary Containment Material or Single-Walled Piping

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Steel

0

0

0

0

0

iv. Other, please specify.

Piping is
above ground

Piping is
above ground

Piping is
above ground

Piping is
above ground



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Flex piping

~

~

~

~

~

iii. Lined trench

~

~

~

~

~

iv. Other, please specify.











v. None

0

0

0

0

0

E. Corrosion Protection (except fiberglass reinforced plastic piping)

i. Fiberglass coated steel

~

~

~

~

~

ii. Impressed current system

~

~

~

~

0

iii. Sacrificial anode system

~

~

~

~

~

iv. Corrosion expert determination

~

~

~

~

~

v. Other, please specify.

N/A

N/A

N/A

N/A



8. Method of Product Dispensing

A. Unsafe Suction (valve at tank)

~

~

~

~

~

B. Safe Suction (no valve at tank)

~

~

~

~

~

C. Pressure

~

~

~

~

0

D. Not Applicable

0

0

0

0

~

9. Spill prevention equipment

~

~

~

~

~

A. Manufacturer and Model

N/A

N/A

N/A

N/A

N/A

B. Capacity (gallons)











10. Overfill prevention equipment

0

0

0

0

~

A. Automatic shutoff device (flapper)
Make and Model

~

~

~

~

~

B. Overfill alarm
Make and Model

0

See cover letter

0

See cover letter

0

See cover letter

0

See cover letter

~

C. Ball float valve
Make and Model

~

~

~

~

~

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 21 of 27

-------
Facility ID No. 9-102271



TanKNc-

Tank No

Wn

——I——

T*N

FST4

0. s

Pipelines Located
Outside Tunnel

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

0

NA

0

NA

0

NA

0

NA

~

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

~

~

F. Groundwater monitoring

~

~

~

~

~

~

~

~

~

~

G. Interstitial monitoring

~

~

~

~

~

~

~

~

~

~

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

~

~

I. Automatic line leak detectors (Yes/No)

NA

No

NA

No

NA

No

NA

No

NA

N/A

If YES, specify type.











J. Line tightness testing

NA

~

NA

~

NA

~

NA

~

NA

0

K. Other method approved by the
Department. Please specify





















XII. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

-

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 22 of 27

-------
Facility ID No. 9-102271

VIII. FINANCIAL RESPONSIBILITY (Check all that apply)

I I Commercial Insurance EH Letter of Credit ~ Local Government Bond Rating Test
EHFinancial Test of Self Insurance	EHsurety Bond	EUother Method Allowed (Specify)	

EUGuarantee	EHTrust Fund	0Exempt: CZIstate or 0Federal Agency

IX. FACILITY DRAWING

Include a drawing showing the general layout of the facility. This drawing should be no larger than 11 by 17 inches and preferably to
scale. This drawing should show the following:

A.	The property boundaries of the facility;

B.	Identification of streets, roads and nearby bodies of water;

C.	Identification of nearby facilities;

D.	Tax Map Key (TMK) Numbers;

E.	Location of buildings at the facility;

F.	The approximate dimensions of the property boundaries and major buildings;

G.	Location of all USTs and dispenser pumps (identified by number/s consistent with the tank & dispenser pump numbers in

Sections XI and XII), and associated pipings; and

H.	Indication of North/South direction.

X. LOCATION MAP

Include a map showing the location of the tanks with respect to nearby landmarks. The map should indicate roads and landmarks to a
level of detail such that the site would be easily located.

XI. DESCRIPTION OF TANK(S) (Complete for each tank at this location)

Tank Number

Tank No

PRT
Otertort

Tank No

PRT-
Ewa

Tank No/nf?5

Tank No

Fwa
Piping
. Loop

Tank No.

1. Status of Tank (Mark only one)

A. Currently in Use



0





0





0



I

a





c



B. Temporarily Out of Use



~





~





~



(

~





c



2. Date of Installation (month/year)

07/2010

05/2006

09/2011

06/2006



3. Estimated Capacity (gallons)

2,000

4,000

236,579

59,500



A. Compartmentalized? Yes/No

No

No

No

No

N/A

Estimated compartment capacity
(gallons)











B. Manifolded? Yes/No

No

No

No

No

N/A

4. Substance Stored

A. Gasoline (Specify product grade)

N/A

N/A

N/A

N/A

N/A

B. Diesel



~





~





~





c





~



C. Gasohol (Including ethanol blends)
Specify product grade

N/A

N/A

N/A

N/A

N/A

D. Kerosene



~





~











c



I

~



Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 23 of 27

-------
Facility ID No. 9-102271

Tank Number

PRT-

Tank No. -

Tank No. =*V

Diamond

Tank No ¦'

£wa '

Tank No. S

Tank No.

E. Used Oil/Waste Oil

~

~

~

~

F. JP-4

r^n

~

~

r~n

~

G. Non-Petroleum Hazardous Substance
(CERCLA name and/or CAS #)

N/A

N/A

N/A

N/A



H. Mixture of Substances (Please specify)

N/A

N/A

N/A

N/A



1. Other, please specify.

F-24

F-24

F-24

F-24



5. Substance Compatible with
Tank and Piping? Yes/No

Yes

Yes

Yes

Yes

N/A

6. Tank (Mark all that apply)

A. Manufacturer and Model

Steel Tank
lnstitute/STI-P3

Steel Tank
lnstitute/STI-P3

N/A

N/A



B. Underwriters Laboratory No.

UL-58

UL-58

N/A

N/A



C. Primary Containment Material or Single-Walled Tank



Fiberglass reinforced plastic

~

~

~

~

~



i. Steel

0

0

~

~

~



ii. Other, please specify.

N/A

N/A

N/A

N/A



D. Secondary Containment Material

i. Fiberglass reinforced plastic

~

~

~

~

~

ii. Steel

0

0

~

~

~

iii. Other, please specify.

N/A

N/A







iv. None

~

~

~

~

~

E. Corrosion Protection (except Fiberglass reinforced plastic tanks)



Fiberglass coated steel

~

~

~

~

~



i. Double-walled steel

0

0

~

~

~



ii. Impressed current system

0

0

~

~

~



v. Sacrificial anode system

~

~

~

~

~

v. Corrosion expert determination

~

~

~

~

~

vi. Other, please specify.

N/A

N/A







7. Piping

A. Manufacturer and Model

Unknown

Unknown

Unknown

Unknown



B. Underwriters Laboratory No.

Unknown

Unknown

Unknown

Unknown



Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16,2018

Page 24 of 27

-------
Facility ID No. 9-102271

Tank Number Tank No. DS2Jd

PRT-

Tank No. Ewa

'¦; h?:v-->Qian»n
-------
Facility ID No. 9-102271

- -i-v.:: " v .«> * v -< ;¦v": - ¦ ^ r-
Tank Number '

SMSp
Tank N

v •

¦J?. Diamond

0. uSa .

l, .... ""

Tank No. ^

LXarmxvd

Tank No/^T

Tank No.

' - /¦
Tank No.

11. Release Detection (Mark all that apply)

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

TANK

PIPE

A. Manual tank gauging

~

NA

~

NA

~

NA

~

NA

~

NA

B. Tank tightness testing

~

NA

~

NA

~

NA

~

NA

~

NA

C. Inventory control

~

NA

~

NA

~

NA

~

NA

~

NA

D. Automatic tank gauging

~

NA

~

NA

~

NA

~

NA

0

NA

E. Vapor monitoring

~

~

~

~

~

~

~

~

O

0

F. Groundwater monitoring

~

~

~

~

~

~

~

~

0

0

G. Interstitial monitoring

0

~

0

~

~

~

~

n

0

0

H. Statistical inventory reconciliation

~

~

~

~

~

~

~

~

0

O

I. Automatic line leak detectors (Yes/No)

NA

No

NA

No

NA

N/A

NA

N/A

NA

N/A

If YES, specify type.











J. Line tightness testing

NA

0

NA

0

NA

0

NA

0

NA

O

K. Other method approved by the
Department. Please specify

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A





XII. DESCRIPTION OF DISPENSER AND UNDER DISPENSER CONTAINMENT

(Attach additional sheet if necessary.)

Dispenser
Unit

Manufacturer of Dispenser

- r

Dispenser Serial #

Under Dispenser Containment
installed (Yes/No) - Installation Date

1





N/A

2





N/A

3





N/A

4





N/A

5





N/A

6





N/A

7





N/A

8





N/A

9





N/A

10





N/A

11





N/A

12





N/A

Application for an Underground Storage Tank Permit - Form No. 2
Date: July 16, 2018

Page 26 Of 27

-------
Facility ID No. 9-102271

XIII. OPERATOR'S CERTIFICATION (Read and sign after completing all sections)

I certify under penalty of law that I have personally examined and am familiar with the information submitted in this and all attached
documents, and that based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the
submitted information is true, accurate, and complete.

(b) (6)

Regional Fuels Officer

	17*	

Name of operato^^Deratorj^^fobrizec^gDresentative (Pr'nt or Type)

Official Title

Signature

(b) (6)

/S/MV/7

Date Signed

Status of Signatory (Mark as appropriate)

1.	Corporation:

2.	Partnership:

3.	Sole proprietorship:

4.	Government entity:

Zl principal executive officer
Llduly authorized representative
^general partner
Q proprietor

Dprincipal executive officer
~ ranking elected official
Eduly authorized employee

XIV. OWNER'S CERTIFICATION (Read and sign after completing all sections)

I certify under penalty of law that I have personally examined and am familiar with the information submitted in this and all attached
documents, and that based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the
submitted information is true, accurate, and complete.

CAPT Marc Delao

Regional Engineer

Official Title

Signature

is Jty If

Date Signed

Status of Signatory (Mark as appropriate)

1.	Corporation:

2.	Partnership:

3.	Sole proprietorship:

4.	Government entity:

dprincipal executive officer
CUduly authorized representative
dlgeneral partner
IZIproprietor

Bprincipal executive officer
["Tanking elected official
IZlduly authorized employee

CNRH LETTER 5750 SER N4/0533 OF MAY 15, 2019 IS INCORORATED BY REFERENCE
AND MADE A PART OF THIS APPLICATION

Application for an Underground Storage Tank Permit- Form No. 2
Date: July 16, 2018

Page 27 of 27

-------
Enclosure 2

-------
-------
Enclosure 3

-------
JOINT BASE
PEARL HARBOR-HICKAM
REGIONAL BASE MAP

Location Map

Hotel Pier

Legend

Rail ¦ Crane Trac*

Installation Boundary

Structures

Recreation Athletic
FMd

Playground

iK^V

ierra Pier

AufielC

CrydocX

	



Sunken Vessel

Bravo Pier

Geographic Coordinate System
Datum WGS t9B4

DATE Aufluit 28 2018

-------
Enclosure 4

-------
JOINT BASE
PEARL HARBOR-HICKAM
REGIONAL BASE MAP

Location Map

Wv.

1 !»:*>«?¦

Legend

Installation Boundary

Buildings

ffOH

Structures

Recreation Athletic
Field

Playground

Storage Tark

Swimming Pool

each Hydrant Pits

AirfielO

Docks ano Warts

Crydocfc

Geographic Coordmata System
Datun WGS 1934

Naval f ao'tje* Sngmeenng Co mm an a riaw a».
Autt Uttaaftcn BevcH AM4

DATE August 28 2019

-S/m

-------
Enclosure 5

-------
Date: 23 Feb 2017

-------
HICKAM AIRFIELD HYDRANT FACILITY

NOT TO SOLE

-------
Enclosure 6

-------
2019 ANNUAL LEAK DETECTION
TESTING REPORT OF J
SECTIONS	OF

PETROLEUM PIPELINES

JOINT BASE PEARL HARBOR -
HICKAM, HAWAII

Prepared for:

Defense Logistics Agency Energy
Fort Belvoir, Virginia

Prepared under:

Naval Facilities Engineering Command Atlantic
Contract N62470-16-D-9007,

Delivery Order N6247019F4016

Submitted by:

Michael Baker International
Virginia Beach, Virginia

Date:

14 March 2019

Michael Baker

INTERNATIONAL

Project: 170482
Task: 4.1.071 A

-------
EXECUTIVE SUMMARY

The purpose of this project is to perform the annual leak detection testing of | sections (^^¦) of
petroleum pipelines at Joint Base Pearl Harbor-Hickam, Hawaii. At Hickam Air Field Facility and NS Pearl
Harbor Facility, testing of| sections	of petroleum pipelines, associated with underground

storage tank systems, is performed in accordance with Hawaii Administrative Rules, Title 11, Chapter 280.1
(HAR 11-280.1), Subchapter 4, §11-280.l-44(4)(A)(i). At NS Pearl Harbor Facility, testing of six sections
(3,305 feet) of petroleum pipelines, associated with aboveground storage tank systems, is performed in
accordance with Defense Logistics Agency (DLA) Energy's Leak Detection Centrally Managed Program
(CMP) as a pollution prevention Best Management Practice (BMP).

Upon mobilization and system review, the ^sections	were revised as follows:

•	The following ^^sections (j^^^^t) were not tested due to being temporarily out-of-service:

o vsjj>- remans

o Tank 55 Valve - ADIT\ PH (
o Tank 54 -
o Truck Rack - VC
o VSm~ VCmrFORFACMlfeMH

•	The length of one section (Truck Fill Loop) was permanently decreased from |
due to a new isolation valve being installed.

•	One section {Hickam Transfer VS Filter Pad) was temporarily separated and tested as two
sections {Hickam Transfer VS^- IVP ^and Hickam Transfer IVP |Q - Filter Pad).

The final 2019 annual leak detection testing event included J sections raraiai of petroleum pipelines.

The annual leak detection testing of | sections (^^^^^|) of petroleum pipelines was performed.^!

between 8 and 28 January 2019, with no detectable leak
above the test methods' minimum detectable leak rates (MDLRs), resulting in passing tests. The annual
leak detection testing of the remaining one section, Tank 47 - ^°f petroleum pipeline was
performed,on 24 January 2019, with a detectable leak above the test method's MDLR, resulting
in a failing test. A leak confirmation/leak locate is being performed under a separate project.

(b)(3)(A)

IV

-------
In accordance with HAR 1 l-280.1-44(4XA)(i), leak detection testing of the following three sections I
|^|) of petroleum pipelines must be performed prior to returning to service:

•	KS'0 VC§

•	Tank 55 Valve

•	Tank 54 - VfM

(t>) (3) (a;

-ADIT%PH{

b)(3) (A)

(b)(3)(A)

In accordance with DLA Energy's Leak Detection CMP, as a pollution prevention BMP, leak detection
testing of the following two sections	of petroleum pipelines should be performed prior to

returning to service.

Truck Rack - VC
• KSH - VC U (FORFAC)

In accordance with HAR 11-280. l-44(4)(A)(i), semi-annual leak detection testing of the following four
sections	of petroleum pipelines, must be initiated on or before the semi-annual anniversary

date of 10 July 2019 due to the MDLRs exceeding the maximum leak detection rate per section volume in
accordance with HAR for annual testing.

•	Hydrant Issue - Type III PH to TVP ^andfpo HSV Issue

•	Hydrant Return - TVP J to Type III PH

•	Hydrant Issue - IV 1^ to IVP

•	AMC Hydrant Loop Outlet Row

In accordance with HAR 11-280.1-44(4)(A)(i), annual leak detection testing of^^ections	of

petroleum pipelines must be initiated on or before the anniversary date of 8 January 2020.

In accordance with DLA Energy's Leak Detection CMP, as a pollution prevention BMP, the annual leak
detection testing of ^ sections	of petroleum pipelines should be initiated on or before the

anniversary date of 17 January 2020.

The semi-annual testing will be repeated in 2019 and the annual testing will be repeated in 2020 under the
DLA Energy's Leak Detection CMP, in accordance with HAR 11 -280.1 -44(4)(A)(i) and as a pollution
prevention BMP; other regulatory obligations are the responsibility of the base and the service.

v

-------
Figure 1-1: JB Pearl Harbor-Hickam Overview

7

-------
Figure 1-2: Hickam Air Field Facility Storage Overview

8

-------
Figure 1-3: Hickam Air Field Facility AMC Hydrants Overview

9

-------
Figure 1-4: Hickam Air Field Facility Type III Hydrants Overview

-------
Figure 1-5: NS Pearl Harbor Facility System Overview

11

-------
Figure 1-6: Red Hill (ADIT 3) Facility System Overview

12

-------
1.5 Protect Team

1.6 Qualifications of Testing Procedures Used

1

13

-------
Table 2-1: Results Summary: Hickam Air Field Facility

Fuel System

.

Test
Section



Product

r'.. ':ntV';' "•.VA

Length
(Feet)

Volume
(Gallons)

Reference
Pressure2
(psi)

Certified
MDLR3
(gph)

Test Date

Result

¦ •























1





Hi

!¦¦

_¦







1



¦i

¦¦

^H

m







1



. m

H

^H

¦







1



H _

¦¦1

^H

¦

H





1

1

¦¦



¦H

¦

m



H

¦



m

¦

I

m

H





1



B

¦¦

^H

m

H





¦



¦i



^H

¦

h





¦



¦



HH

¦

m







1



¦¦¦



¦

¦

m _





wSSm

¦



	¦¦

K

¦

¦

¦

¦







¦



H

H

¦

m

m







¦



H

H

¦

m

m





¦

¦¦HHH

¦¦



¦H

m





H

¦



H

Hi

HH

¦

m





¦



H

¦

¦¦

m

m



H

¦



H

H



¦

m





¦





¦

Hi

m

m





¦



¦¦

¦

|^H

m

m





¦



¦¦

H

¦

¦







¦





¦1

j^m

¦

m











15

-------
Table 2-2: Results Summary: NS Pearl Harbor Facility

Fuel
System

Test
Section

Designation1,2

• - . I-

Product

Length
(Feet)

Volume
(Gallons)

Reference
Pressure3
(Psf)

Certified
MDLR4
(eph)

Test Date

Result





























1







¦1

¦

¦

¦





¦



¦1

¦



¦

m

¦¦¦¦



1



¦i

¦



¦





¦¦

1





¦

¦

. ¦ _h

m





1



Mi

¦

H

¦

m



m

1



H

¦1

Hi

¦

m

HH

H

1



H

¦

¦

¦1

m

HBH

H

1



Mi

¦

¦

¦

m

¦HHB

H



1



H

¦



¦

m

h^hi

H



¦



¦

¦

¦

m

m



Bi



¦

1^1

¦1

¦



m

m



H

¦



m

¦

mm

m

¦



H

¦



¦¦

¦

H

¦

H



¦1

¦

H



¦

j^m

<^m

m

H



Ml

¦





¦i

m

¦

¦i

m

¦ H

HI

¦







m

H

mm

m

h^hi

H

¦





m

m



m

¦



¦1

¦





mm

m



m





¦1

¦
¦







¦
¦





16

-------
Enclosure 7

-------


III





2019 ANNUAL STATIC LIQUID
PRESSURE TESTING REPORT

OF

(b)(3) (A)

SECTIONS (I

(b)(3) (A)

.



OF PETROLEUM PIER

PIPELINES

JOINT BASE PEARL HARBOR
HICKAM, HAWAII

Prepared for:

Defense Logistics Agency Energy
Fort Belvoir, Virginia

Prepared under:

Naval Facilities Engineering Command Atlantic
Contract N62470-16-D-9007,

Delivery Order N6247019F4016

Submitted by:

Michael Baker International
Virginia Beach, Virginia

Date:

18 March 2019

Michael Baker

NTERNATIONAL

Project: 170482
Task: 4.1.076

-------
Figure 1-1: JB Pearl Harbor-Hickam Overview

4

-------
Figure 1-2: Hotel and Kilo Piers Overview

5

-------
1.5 ' Project Team

1.6 Qualifications of Tester and Testing Procedures Used

6

-------
Table 2-1: Results Summary

8

-------
3.0 CONCLUSIONS AND RECOMMENDATIONS

3.1 Conclusions

The three sections	°f petroleum pier pipelines passed the 2019 annual static liquid pressure

testing. Four sections	of petroleum pier pipelines were not tested.

3.2	Recommendations

-------
Michael Baker

INTERNATIONAL

Michael Baker International
TKST REPORT
Joint Base Pearl Harbor-Hickam. Hawaii

APPENDIX A

CITED REGULATIONS

-------
Coast Guard, DHS

§156,170

under §§ 154.710 and 155.700 of this chap-
ter, has filled out and signed the dec-
laration of inspection form described in
paragraph (o) of this section,

(b)	No person In charge may sign the
declaration of inspection unless he or
she has determined by inspection, and
indicated by initialling in the appro-
priate space on the declaration of in-
spection form, that the facility or ves-
sel, as appropriate, meets §156.120,

(c)	The declaration of inspection may
be in any form but must contain at
least:

(1)	The name or other identification
of the transferring vessel or facility
and the receiving- vessel or facility;

(2)	The address of the facility or loca-
tion of the transfer operation if not at
a facility;

(3)	The date and time the transfer op-
eration is started;

(4)	A list of the requirements in
§156.120 with spaces on the form fol-
lowing each requirement for the person
in charge of the vessel or facility to in-
dicate by initialling that the require-
ment is met for the transfer operation;
and

(5)	A space for the date, time of sign-
ing, signature, and title of each person
in charge during transfer operations on
the transferring vessel or facility and a
space for the date, time of signing, sig-
nature, and title of each person in
charge during transfer operations on
the receiving' facility or vessel certi-
fying that all tests and inspections
have been completed and that they are
both ready to begin transferring prod-
uct; and

(6)	The date and time the transfer op-
eration is completed,

(d)	The form for the declaration of in-
spection may incorporate the declara-
tion-of-inspection requirements under
46 CFR 35.35-30,

(e)	The vessel and facility persons in
charge shall each have a signed copy of
the declaration of inspection available
for inspection by the COTF during the
transfer operation.

(f)	The operators of each vessel and
facility engaged in the transfer oper-
ation shall retain a signed copy of the
declaration of inspection on board the

vessel or at the facility for at least 1
month from the date of signature.

[CGD 75-124, 45 FR 7177, Jan. 31, 1980. as
amended by CGD 86-034, 55 FR 36256, Sept. 4,
1000; CGD 93-056, 61 FR 41461, Aug. 8, 1996]

§ 156.160 Supervision by person in
charge.

(a)	No person may connect or dis-
connect a hose, top off a tank, or en-
gage in any other critical procedures
during the transfer operation unless
the person in charge, required by
§ 156.120(s), supervises that procedure.

(b)	No person may start the flow of
oil or hazardous material to or from a
vessel unless instructed to do so by ei-
ther person in charge.

(c)	No person may transfer oil or haz-
ardous material to or from a vessel un-
less each person in charge is in the im-
mediate vicinity and immediately
available to the transfer personnel,

[CGD 75-124, 45 FR 71T7, Jan. 31, 1980, as
amended by CGD 86-034, 55 FR 36256, Sept. 4,
1990]

§156.170 Equipment tests and inspec-
tions.

(a)	Except as provided in paragraph
(d) of this section, no person may use
any equipment listed in paragraph (c)
of this section for transfer operations
unless the vessel or facility operator,
as appropriate, tests and inspects the
equipment in accordance with para-
graphs (b), (c) and (f) of this section
and the equipment is in the condition
specified in paragraph (c) of this sec-
tion.

(b)	During any test or inspection re-
quired by this section, the entire exter-
nal surface of the hose must be acces-
sible,

(c)	For the purpose of paragraph (a)
of this section:

(1) Each nonmetallic transfer hose
must:

(i)	Have no unrepaired loose covers,
kinks, bulges, soft spots or any other
defect which would permit the dis-
charge of oil or hazardous material
through the hose material, and no
gouges, cuts or slashes that penetrate
the first layer of hose reinforcement as
defined in §156.120(i),

(ii)	Have no external deterioration
and. to the extent internal inspection

495

-------
§ 156.170

33 CFR Ch. I (7-1-18 Edition)

is possible with both ends of the hose
open, no internal deterioration;

(iii)	Not burst, bulge, leak, or abnor-
mally distort under static liquid pres-
sure at least l'i times the maximum
allowable working pressure; and

(iv)	Hoses not meeting1 the require-
ments of paragraph (c)(l)(i) of this sec-
tion may be acceptable after a static
liquid pressure test is successfully
completed in the presence of the COTP.
The test medium is not required to be
water.

(2)	Each transfer system relief valve
must open at or below the pressure at
which it is set to open;

(3)	Each pressure gauge must show
pressure within 10 percent of the actual
pressure;

(4)	Each loading arm and each trans-
fer pipe system, including each metal-
lic hose, must not leak under static liq-
uid pressure at least IV2 times the max-
imum allowable working pressure; and

(5)	Each item of remote operating or
indicating equipment, such as a re-
motely operated valve, tank level
alarm, or emergency shutdown device,
must perform its intended function.

(d)	No person may use any hose in
underwater service for transfer oper-
ations unless the operator of the vessel
or facility has tested and inspected it
in accordance with paragraph (c)(1) or
(c)(4) of this section, as applicable.

(e)	The test fluid used for the testing
required by this section is limited to
liquids that are compatible with the
hose tube as recommended by the hose
manufacturer,

(f)	The frequency of the tests and in-
spections required by this section must
be:

(1)	For facilities, annually or not less
than 30 days prior to the first transfer
conducted past one year from the date
of the last tests and inspections:

(2)	For a facility in caretaker status,
not less than 30 days prior to the first
transfer after the facility is removed
from caretaker status; and

(3)	For vessels, annually or as part of
the biennial and mid-period inspec-
tions.

(g)	If a facility or vessel collects
vapor emitted to or from a vessel cargo
tank with a vapor control system, the
system must not be used unless the fol-

lowing tests and inspections are satis-
factorily completed;

(1)	Each vapor hose, vapor collection
arm, pressure or vacuum relief valve,
and pressure sensor is tested and in-
spected in accordance with paragraphs
(b), (c), and (f) of this section;

(2)	Each remote operating or indi-
cating device is tested for proper oper-
ation in accordance with paragraph (f)
of this section;

(3)	Each detonation arrester required
by 33 CFR 154.2105, 154.2108(b), 154.2109,
154.2110, 154.2111, and 154.2204, or 46 CFR
39.4003, and each flame arrester re-
quired by 33 CFR 154.2103, 154.2105(j),
and 154.2203 has been inspected inter-
nally within the last year, or sooner if
operational experience has shown that
frequent clogging or rapid deteriora-
tion is likely; and

(4)	Each hydrocarbon and oxygen an-
alyzer required by 33 CFR 154.2105(a)
and (j), 154.2107(d) and (e), and 154.2110
or 46 CFR 39,4003 is calibrated;

(i)	Within the previous two weeks, or

(ii)	Within 24 hours prior to operation
when the vapor control system is oper-
ated less frequently than once a week.

(h)	Upon the request of the owner or
operator, the COTP may approve alter-
native methods of compliance to the
testing requirements of paragraph (c)
of this section if the COTP determines
that the alternative methods provide
an equal level of protection.

(i)	Notwithstanding the general pro-
visions of 33 CFR 156.107(a) relating to
the authority of the Captain of the
Port to approve alternatives, the owner
or operator may request the written
approval of the Commandant (CG-
ENG), U.S. Coast Guard, 2100 2nd St.
SW., Stop 7126. Washington, DC 20593-
7126, for alternative methods of compli-
ance to the testing and inspection re-
quirements of paragraph (g)(3) of this
section. The Commandant (CG-ENG)
will grant that written approval upon
determination that the alternative
methods provide an equivalent level of
safety and protection from fire, explo-
sion, and detonation. Criteria to con-
sider when evaluating requests for al-
ternative methods may include, but are
not limited to: operating and inspec-
tion history, type of equipment, new

496

-------
Enclosure 8

-------
Naval Facilities Engineering Command

ENGINEERING AND EXPEDITIONARY WARFARE CENTER

Contract Report
CR-NAVFAC EXWC-CI-18134
October 2017

CATHODIC PROTECTION OF POL SYSTEMS
2016 ANNUAL SURVEY & REPAIRS

Naval Supply Fleet Logistics Center Pearl Harbor
Honolulu, Hawaii

PRL 16-CP
RHL 16-CP

Contract No: N39430-15-D-1631, DO 0002

Prepared For:

Naval Facilities Engineering and Expeditionary Warfare Center

By:

Burns & McDonnell
9400 Ward Parkway
Kansas City, MO 64114

Distribution authorized to U.S. Government agencies and their contractors; Administrative/Operational Use; October 2017.

Other requests for this document shall be referred to NAVFAC EXWC. 	

-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
Naval Facilities Engineering Command

ENGINEERING AND EXPEDITIONARY WARFARE CENTER

Contract Report
CR-NAVFAC EXWC-CI-XXXX

CATHODIC PROTECTION OF POL SYSTEMS

2018 ANNUAL SURVEY & REPAIRS

Naval Supply Fleet Logistics Center Pearl Harbor

Honolulu, Hawaii

PRL 18-CP
RHL 18-CP

Contract No: N39430-15-D-1633 DO N3943018F4006

Prepared For:

Naval Facilities Engineering and Expeditionary Warfare Center

By:

Pond & Company, Inc. 3500
Parkway Lane, Suite 500.

Peachtree Corners, GA 30092

June 2018

Distribution authorized to U.S. Government agencies and their contractors: Administrative/Operational Use; June 2018 Other
requests for this document shall be referred to NAVFAC EXWC.

Printed on recycled paper

-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
Enclosure 9

-------
IN/VniC

slaval Facilities Engineering Command

ENGINEERING AND EXPEDITIONARY WARFARE CENTER

Contract Report
CR-NAVFAC EXWC-CI-XXXX
JUNE 2017

CATHODIC PROTECTION OF POL SYSTEMS
2016 ANNUAL SURVEY

Hickam AFB
Honolulu, HI

HIC 16-CP (Final)

Contract No: N39430-15-D-1631 DO # 002

Prepared For:

Naval Facilities Engineering and Expeditionary Warfare Center

By:

Burns & McDonnell
9400 Ward Parkway
Kansas City, MO 64114

Distribution authorized to U.S. Government agencies and their contractors: Administrative/Operational Use: June 2017. Other
requests for this document shall be referred to NAVFAC-EXWC.

0%

^9 Printed on recycled paper

-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
Naval Facilities Engineering Command

ENGINEERING AND EXPEDITIONARY WARFARE CENTER

Contract Report
CR-NAVFAC EXWC-CI-18200

CATHODIC PROTECTION OF POL SYSTEMS
2017 ANNUAL SURVEY & REPAIRS

Joint Base Pearl Harbor-Hickam
Honolulu, Hawaii

HIC 17-CP

Contract No: N39430-15-D-1678, TO N3943017F4130

Prepared For:

Naval Facilities Engineering and Expeditionary Warfare Center

By:

ENTER PRISE ENGINEERING INC
2525 Gambell Street, Suite 200
Anchorage, AK 99503

April 2018

Distribution authorized to U.S. Government agencies and their contractors; Administrative/Operational Use; April 2018.
Other requests for this document shall be referred to NAVFAC EXWC.

-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
-------
Enclosure 10

-------
(b)(3)(A)

FINAL 2018 ANNUAL LEAK
DETECTION TESTING REPORT
OF 17 BULK FIELD-
CONSTRUCTED UNDERGROUND
STORAGE TANKS AT RED HILL
FUEL STORAGE COMPLEX

JOINT BASE PEARL HARBOR-
HICKAM, HAWAII

Prepared for:

Defense Logistics Agency Energy
Fort Belvoir, Virginia

Prepared under:

Naval Facilities Engineering Command
Atlantic Contract N62470-16-D-9007
Delivery Order N6247018F4143

Submitted by:

Michael Baker International
Virginia Beach, Virginia

T

Date.

23 January 2019

Michael Baker

INTERNATIONAL
Project: 169227
Task: 3.0

-------
1.5 Project Team

1.6 Qualifications of Testing Procedures Used

7

-------
Table 2-1: Results Summary

9

-------
4.0

REFERENCES

4.1 "Final 2017 Annual Leak Detection Report of 18 Bulk Field-Constructed Underground Storage
Tanks at Red Hill Fuel Storage Complex, Joint Base Pearl Harbor-Hickam, Hawaii"; Prepared for:
Defense Logistics Agency Energy, Fort Belvoir, Virginia; Prepared under; Naval Facilities
Engineering Command Atlantic Contract N62470-16-D-9007-0004; Submitted by: Michael Baker
International, Virginia Beach, Virginia; Date: 23 January 2018.

4.2 "Final 2018 Annual Leak Detection Report of Two Bulk Field-Constructed Underground Storage
Tanks at Red Hill Fuel Storage Complex, Joint Base Pearl Harbor-Hickam, Hawaii"; Prepared for:
Defense Logistics Agency Energy, Fort Belvoir, Virginia; Prepared under: Naval Facilities
Engineering Command Atlantic Contract N62470-16-D-9007, Task Order N6247018F4006;
Submitted by: Michael Baker International, Virginia Beach, Virginia; Date: 15 June 2018.

4.3

11

-------